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191-101
SFD 4/10/2020VTL 4/17/20 DSR-4/9/2020 SFD 4/10/2020 Well To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 1 CASED HOLE Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.Williams(dreadcasedhole com 11 -Dec -19 1R-23 (111,17 rt /CD '11101 X1712 RECEIVE® /nDEC }'} /2'�0 2019 P" OGCC 50-029-22200-00 Date : Vl' & ( `I READ CASED HOLE, INC, 4141 B STREET, SURE 308, ANCHORAGE, AK 99503 PHONE: (907)245.8951 E-MAIL: READ-ANCHORAGE@READCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM https:6readc oto-my.sharepowtcmNpusoosydieoe_willinma readcasedhole com/Dom .tdD DrivdAchiv WaswrTu lat File mplates istrbudoMrmsmitWSheeWConoeoPhillips_Tremmitdocn 31712 191101 Company: Log Date: Log No.: Run No.: Pipe Description: Pipe Use: Pipe Description: CASED Memory Multi -Finger Caliper HOLE Log Results Summary ConocoPhillips Alaska, Inc. December 11, 2019 15723 2 3.5 inch 9.3 Ib. J-55 EUEABMOD Tubing 7 inch 26 Ib. L-80 NSCC Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Bottom Log Interval: Inspection Type: Restriction Inspection COMMENTS: This caliper data is tied into the gamma K1 marker at 11,099 feet. 1 R-23 Kuparuk Alaska 50-029-22200-00 10,963 Ft. (MD) 11,602 Ft. (MD) 11,602 Ft. (MD) 11,665 Ft. (MD) Two passes were made over the intended log interval. This report is a combination of the two caliper passes. This log was run to assess the condition of the casing with respect to I.D. restrictions following a cement and under -ream procedure. Both caliper passes recorded cement deposit remnants from -11,618 feet to -11,620 feet and intermittent cement remnants from -11,645 feet to -11,664 feet, restricting the I.D. to 5.87 inches at 11,649 feet in Pass 1 and 5.85 inches at 11,651 feet in Pass 2. A 3-D log plot overlay of both caliper passes over the casing logged and a graph illustrating the minimum recorded diameters of both caliper passes on a joint -by -joint basis across the casing logged are included in this report. The caliper recordings indicate the 7 inch casing logged appears to range from good to fair condition with respect to internal corrosive and mechanical damage, with a maximum recorded wall penetration of 34% in a line of corrosion in joint 4 (11,664 ft). Recorded damage appears as isolated pitting, a line of pits, and line corrosion. No significant areas of cross-sectional wall loss are recorded throughout the casing logged. This is the second time a READ caliper has been run in this well and the 7 inch casing has been logged. Due to the purpose of this log and short duration between the current and previous log (September 14, 2019) no comparison graph is included in this report. 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Description ?:rcantWDH PenetUon Joint Deep t,y Line Corrosion 34 4 11,664 Ft. (MD) Line Corrosion 31 3 11,656 Ft. (MD) Line Corrosion 31 2 11,635 Ft. (MD) No other significant wall penetrations (> 14%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the casing logged, READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(,)readcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: 0 scrlPiloe Deposits Deposits Minimum P,i oided LDiame[ei Joint Depth 5.85 in (Pass 2) 3 11,651 Ft. (MD) 5.87 in (Pass 1) 3 11,649 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. B. Suhanek C. Waldrop J. Condio READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(a)readcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Hang -Up Hang -Up Hang -Up Hang -Up d .o E Z Z E 0 Minimum Measured Diameters (in.) 1.75 2 11,603 11,618 11,641 1,661 _ CASED HOLE Minimum Diameter Profile(Pass 1 Well: 1R-23 Survey Date: December 11, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 6.276 inches d .o E Z Z E 0 Minimum Measured Diameters (in.) 1.75 2 11,603 11,618 11,641 1,661 CASED HOLE Well: IR -23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Minimum Diameter Profile(Pass Survey Date: December 11, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches Tubing I.D.: 6.276 inches Minimum Measured Diameters (in.) 1.75 2 3 4 5 6 11,602 11,617 11,642 1,662 tE ti L.. CL w Pipe Nom.CD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 NSCC 6.276 in 11,603 ft 11 665 ft Penetration (%wall) 10 8 6 4 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of'oints analyzed total = 4 1 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of' i ma (total = 0 0 3 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 2 3 4 Bottom of Survey = 4 CASED HOLE Body Region Analysis (Pass 1) Well: 1R-23 Survey Date: December 11, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 12pf L-80 NSCC Analyst: C. Waldrop Pipe Nom.CD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 NSCC 6.276 in 11,603 ft 11 665 ft Penetration (%wall) 10 8 6 4 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of'oints analyzed total = 4 1 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of' i ma (total = 0 0 3 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 2 3 4 Bottom of Survey = 4 PipeNom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 NSCC 6.276 in 11,602 f . 11,665 It Penetration (% wall) 10 8 6 4 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of ioints anal zed total = 4 1 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole um damaged 1=3 2 0 1 0 0 Damage Profile (% wall) IM1111111 Penetration body Metal loss body 0 50 100 1 2 3 4 Bottom of Survey = 4 CASED HOLE Body Region Analysis (Pass 2) Well: 1 R-23 Survey Date: December 11, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 p2f L-80 NSCC Analyst, C. Waldrop PipeNom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 NSCC 6.276 in 11,602 f . 11,665 It Penetration (% wall) 10 8 6 4 2 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of ioints anal zed total = 4 1 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole um damaged 1=3 2 0 1 0 0 Damage Profile (% wall) IM1111111 Penetration body Metal loss body 0 50 100 1 2 3 4 Bottom of Survey = 4 CASED HOLE Well: 1R-23 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Joint Tabulation Sheet (Pass 1) Survey Date: December 11, 2019 Analyst: C. Waldrop Pipe Description 7 in. 26 ppf L-80 NSCC Casing Nom. ID Body Wall Top Depth 6.276 in. 0.362 in. 11,603 ft. Bottom Depth 11,665 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Min. Loss I.D. % (in.) Comments Damage Profile (% wall) 0 50 100 1Pl�ff66 1603 0 0.05 14 2 6.00 Lt. Deposits. 2 0.09 0.11 31 2 6.00 Line Corrosion. Lt. De osits. 30.09 0.11 31 7 5.87 Line Corrosion. De osits. 40.14 0.12 34 10 6.12 Line Corrosion. Lt. D osits. Penetration Body Metal Loss Body Page 1 =_ I CASED HOLE Well: 1 R-23 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Joint Tabulation Sheet (Pass z) Survey Date: December 11, 2019 Analyst: C. Waldrop Pipe Description 7 in. 26 ppf L-80 NSCC Casing Nom. ID Body Wall Top Depth 6.276 in. 0.362 in. 11,602 ft. Bottom Depth 11,665 ft. Joint )t. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Min. Loss I.D. % (in.) Comments Damage Profile (%wall) 0 50 100 1 11602 0 0.04 11 2 5.92 Lt. Deposits. 2 11617 0.06 0.08 21 3 6.05 Isolated Pittin Lt. Deposits. 3 11642 0.07 0.08 23 6 5.84 Isolated Pitting, Deposits. 4 11662 0.06 0.08 21 6 6.10 Line of Pits. Lt. Deposits. 'Penetration Body Metal Loss Body Page 1 =_ CASED HOLE Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration (Pass 1) Survey Date: December 11, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 4 at depth 11,664.011 ft. Tool speed = 48 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 93% Tool deviation = 64° Finger = 17 Penetration = 0.123 in. Line Corrosion 0.12 in. =.34% Wall Penetration HIGH SIDE = UP CASED HOLE Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration (Pass 1) Survey Date: December 11, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 3 at depth 11,656.001 ft. Tool speed = 48 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 92% Tool deviation = 65° Finger =17 Penetration = 0.111 in. Line Corrosion 0.11 in. = 31% Wall Penetration HIGH SIDE= UP =_ CASED HOLE Cross-sectional Illustration (Pass 1) Well: 1 R-23 Survey Date: December 11, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 NSCC Analvst C WaWrnr, Cross Section for Joint 3 at depth 11,649.281 ft. Tool speed = 48 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 98% Tool deviation = 64° Minimum I.D. = 5.872 in. Deposits Minimum I.D. = 5.87 in. HIGH SIDE = UP CASED HOLE Cross-sectional Illustration (Pass 2) Well: 1 R-23 Survey Date: December 11, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 NSCC Analyst- _ C. Waldrop Cross Section for Joint 3 at depth 11,651.210 ft. Tool speed = 55 ft/min Nominal ID = 6.276 in. Nominal OD = 7 in. Remaining wall area = 99% Tool deviation = 68° Minimum I.D. = 5.845 in. Deposits Minimum I.D. = 5.85 in. HIGH SIDE = UP INJ Legal Wellname 1R-23 Common Wellname1R-23 Last Tag KUP An^ale1l°^ 0°mh mKB1 no Das LaalMa4By Weubore Last Tag: SLIM 11135,0 912112019 letng 1R-23 Conoco Won, Alaska, Inc. PIaMh KUPAF Rev Raasop_ Puffhb,n0lell 11/1912019 famaj 1R-23 INJ Legal Wellname 1R-23 Common Wellname1R-23 Last Tag AKAll Wellbores Schem An^ale1l°^ 0°mh mKB1 no Das LaalMa4By Weubore Last Tag: SLIM 11135,0 912112019 letng 1R-23 Last Rev Reason 1K -29A, "gaga isVieo. Ann°Mlon End pale Let Mad By Wellbore Ve1lul -manes, Boost Rev Raasop_ Puffhb,n0lell 11/1912019 famaj 1R-23 Casing Strings ._...................__ fiat push spa.=(In) Ceg Ow OD fin) N)(in) TOP(flKB) eNp°pMag1th INKS) da Maatl W°ubox, -B.Isa sesCONDUC44.0 123.0 P2ou 62.50 ED 1R-23SURFACE 896 892 42.0 6,330.8 4.0]2.4 36.00 1R-2329.2 12,1]].] ],002.5 2600 1843Tubing Stringssone Nwnlnal ON pepIM1 eel pcldNlrvglWCTDRMpw OD llnl Iplin iop INNBI (KKe) (11NB1 WI(IbM) ap Won.TUBING WO 312 2.99 38.3 it,fi09.8 6126) 9.30 JO 1R-23Complegon Details --Top(T ) Tep lnG omimlTop legal (KKB) 1'I Mm E. C°m p 11n) i ibpa 3PFETx M:I,618.0 GAs uPf, 6250.] 3&3 30.3 001 HANGER FMC GEN IV TUBING HANGER 3.5001R-23 1,816.0 1.719.41 39,09 SAFETY VLV CAMCOTRDP-1A AFETYVALVE 2.012 1R-23 17529.9 6,689.11 61.07 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 1R-23 11,56].5 6,]06.] 61.89 PER BAKER PER 3.000 1R-23 11,5813 6,713.1 51.90 PACKER BAKER HBRETRIEVABLE PACKER 2.890 10.-23 1,5 W 1.5 6.720.8 61.91 NIPPLE OTIS XN NIPPLE NOGG 2150 IR -21 11,609.2 6,]26.3 61.86 SOS BAKER SHEAR OUT SUB 2,992 1 1R-23 Other In Kole.(Whelbis retrievable Plains. vateredi, pumps, fish. a so.i . *op Rop)) Top (NKBI 0931) Top lmll°) pea Cum Run Date ID (in) WNlbore 11,689A 6,]60161.66 WHIPSTOCK NODhern Solutions 350-700 High Expansion 9/2812019 0.900 IR -23 Wedge. sel4scogrees ROHS. WRAlag sell6loW(TWOWtop01HEW). GAL6.6' Max OD 2.625' 9VRFACE; <P.pA,J9p.6 Line Details, :,°. ., Top lTvpl Nominal lD rop lNKB) INK$) Top ma l'I Xam pw cem Onl wallbor. Oas uFi;flAw.6 42.0 42.0 0.02 HANGER 8.921 1R-23 44.01 ed 01 0.02 CONDUCTOR 15.062 10.-23 PerForatlons S Slots snot 0n Tap Tag Bpn mp) phi TaP(M(e) 6m MIKE) mica) Linkaazone Db ) w Com TyNlan. w NIPPLE: 11 P"p 11.590.0 11,592.0 6,]17.3 6,)18.2 UNIT D, iR-23 1111912019 3.0 CMT SOZ 2"Paalilm 3 aid 0deg IR -23 pbafiing. 11,]10.0 11,]]0.0 6.77ol 6,603.1 C-2, C-1, UNIT 1191992 10.0 IPERF 4.5"Cs9Go;60deg ph 10..23 8,1R-23 Pop; 11,8676 Mandrel Inerts sl all PACs 11,$91,9 Pml TO°mp) WM IMch 6u° TRORun No top lKKa) f Make MotlN Op (in) fiary Type Tyq (In) (pill Rue Dew C. W°Iboro CMT spi: U.N... 3,250) 2,493.2 CAMCO KBUG-M 1 GASLIFT DMY BK 0.000 0.0 1012711992 1R-23 I1,58].p NIPPLE: 1159).9 2 11,d84S 6,66)5 OTIS LBD 1112 1 GAS LIFT IDMY RM 0.000 00 41;1992 IR -23 Stlmulefion Intervals 6Gn pate Proppanl peelpneJ llbf Porous In Po,mallon 11>) 10111/199500:00 Frac Summary aid# Ron D^N Top INKS) le. flKIB Linkto Fluldiii Vo1B1wn(bbp Volearaiph9 1 10/1 t/1995 11110.0 11,]]0.0 Sp8; 11.$00.3 WHIPSTOCK: 11,6639 KP60; 11,Tinp 770.0 IPERF 11.710.0.11 PRPoUCTION 992 12,177,T ConocoPhillips Alaska, Drilling & Wells Coiled Tuhin¢ Drillinw 1R-23 PDC Loa 6370 6380 6390 6410 6420 5430 m ConocoPhillips � Alaska September 4, 2019 I R-23Pre-CTD Procedure Page 6 of 7 Davies, Stephen F (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, November 21, 2019 3:41 PM To: Davies, Stephen F (CED) Cc: Ohlinger, James J Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421, 319-493) - Questions Hello Steve, The existing perforations will be isolated with cement (Sundry #319-493). The cement portion of that work has not occurred yet, but will hopefully commence sometime next week. ConocoPhillips does not plan to attempt to drill 1R-231-1-01, 111-231-1-02, and 1R -23L1-03 so those permits can be withdrawn. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Thursday, November 21, 2019 2:22 PM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421, 319-493) - Questions Hi Ryan, I'm working on the Permit to Drill applications for the laterals that will be drilled from 111-23, and I need a bit of clarification. 1. Will all existing perforations in KRU 1R-23 be isolated with cement prior to beginning the currently proposed drilling operations? 2. Does ConocoPhillips wish to withdraw the Permit to Drill applications for 1R -23L1-01, 1R -23L1-02, and 1R-231-1- 03? Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information, The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies0alaska.gov. From: Davies, Stephen F (CED) Sent: Monday, September 16, 2019 11:20 AM To: McLaughlin, Ryan <Rvan.McLaughlin @conocoohillips.com> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Thank you Ryan. Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies[aalaska.gov. From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Monday, September 16, 2019 11:18 AM To: Davies, Stephen F (CED) <steve.davies@alaska,,zov> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Steve, That is correct. The high expansion wedge is non -isolating. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G 5t, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Monday, September 16, 2019 11:16 AM To: McLaughlin, Ryan <Rvan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Ryan, Could you please confirm that the proposed High Expansion Wedge will not isolate the existing C -sand perforations in KRU 1R-23? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.dayiesPalaska.gov. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Kai Starck CTD Director ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 R-23 Permit to Drill Number: 191-101 Sundry Number: 319-493 Dear Mr. Starck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e . Price Chair DATED this _ day of November, 2019. 3BDMS±{ NOV 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED VU fill a 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 2 Chan��}P El Plug for Redrill El'erforate New Pool El Repair Well ElRe-enterSusp Well ElOther: �KEI 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service 0 191-101 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-029-22200-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25635, ADL 25636, ADL 25627 KRU 1 R-23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,180 feet Plugs measured None feet true vertical 7,004 feet Junk measured None feet Effective Depth measured 12,178 feet Packer measured 11,581 feet true vertical 7,003 feet true vertical 6,713 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 123' MD 123' TVD SURFACE 6,289 feet 9 5/8 " 6,331' MD 4072' TVD PRODUCTION 12,149 feet 7 12,178' MD 7003' TVD Perforation depth: Measured depth: 11710-11770 feet True Vertical depth: 6774-6803 feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 11,609' MD 6,726' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER HB RETRIEVABLE 1 11,581' MD 6,713' TVD SSSV - CAMCO TRDP-1A SSSV 1,816' MD 1,794' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:I Shut-in Subsequent to operation: I Shut -In 14. Attachments (required per20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-4221 Contact Name: Ryan MCLaughlin� Authorized Name: Kai Starck 7 Authorized TitleCTD Director contact Email: ryan.mclaughlin@cop.com : r / Contact Phone: (907) 265-6218 Authorized Signature: ' � C Date: 4 ' J 6 Form 10-404 Revised 4/2017 AB 012019 Submit Original Only 1 R-23 SET WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 9/28/19 DRILLING RUN 1: PERFORM STATIC BOTTOM HOLE PRESSURE SURVEYS SUPPORT- @ 11377' (3892 PSI) & 11590' (3937 PSI). CAPITAL RUN 2: SET TOP OF NORTHERN SOLUTIONS WEDGE @ 11682', WEDGE ORIENTATED TO 4.6 DEG ROHS, CCL TO TOW = 16.5', CCL STOP DEPTH = 11665.5', RA TAG @ 11691. LOG CORRELATED TO K1 MARKER @ 11099'. 10/15/19 DRILLING Trim 2 pieces of coiled tubing for Tipton testing, swap reels, Prep reel SIDETRACK for stabbing to injector. Prep stuffing box for new CT 10/16/19 DRILLING Completed reel swap, RD & ND BOPE, moved from 1A -Pad to 1 R - SIDETRACK Pad, spotted rig over 1 R-23, began RU checklist 10/17/19 DRILLING Complete RU, test BOP's (250 low / 3500 high), change out bales, PD SIDETRACK BHA #1 Window Assembly, RIH, begin milling window in 7" casing 10/18/19 DRILLING Complete milling window & rat -hole, dress window, POOH, PUD BHA SIDETRACK #1, PD BHA #2 Build Assembly, Drill Build 11710 to 11755, POOH, PUD BHA #2, PD BHA #3 Lateral Assembly, RIH, difficulty running through window, decison made to POOH, Begin PUD BHA #3 10/19/19 DRILLING Complete PUD BHA #3, PD BHA #4 Window Milling Assembly, RIH, SIDETRACK dressed window, POOH, PUD BHA #4, PD BHA #5 Lateral Assembly, RIH, drill from 11,755' to 12,155', pulled wiper trip, drilled to midnight depth of 12,520' KUP INJ WELLNAME 7R-23 WELLBORE 1R-23 Well Attributes Max Angle & MD TD ConocoPhilliill ps g Alaska. Inc_ KIIPPFIIN RI VF R I IN IT ........ W¢IIMre 5181us Ic119 MO_I%K81 pq 81m KKB lR-a,larm013 u:m:m AM Last Tag VerLLal xlemetic lecruyl pnnDINIDn Dep%I MKB) End Date WeIIWm Lear MDtl By Last Tag'SLM 11,735.0 9212019 1R-23 Inicriq ..............._.............. ... ......_.................. Last Rev Reason Annotation End Data WeIIWIe Laz[Mctl By RANGER; 989 Rev ReasD¢Set Whipstock 9...... 1R-23 tanto] Casing Strings Laain. oevir"oup oD(in) mpp CONDUCTOR 16 15.06 Top lnrc8l SOedo 1%KBf 3aoepul"g—wuGun p...Grade Top Thenad 440 112'!10 1230 62.50 RAA WELDED Cavin. Descripllon Bobo) IO(Inl SURFACE 998 8.92 TOP I%KB) Se ce nothr, Ser O.pth("Cog W&Lan (I G,ade Top Thread 42.0 6,330.8 4,m2.4 3fi 00 JS5 BTO Leung Description OD lin, ID IM) PRODUCTION ] 628 Top l%KBI SH D.pth l%KB) Sna napN lrv0)... WIILen ll... latest Top Thrad 29.2 12,1 A.] ],0025 26.00 L-80 NSCC CONDUCTOR: M 6190 Tutting Strings Tubing Deacrlpllon String Ma... ID(I TUBING WO 3112 2.99 TDp MR) Sel Depth UT -15a Depth nVDI I... WHIbdt1 Grada TOP ConnMion 38.3 11,609.9 6,O6J 1930. J-55 EUEABMOD Completion Details SAFETVWic 1.eta0 Top ITVD) TDp Incl Top 1%KB) 1%KB, 1°1 Imm Dee Nominal Com IDpD) 383 38.3 0.01 HANGER FMC GEN IV TUBING HANGER 3.500 1,816.0 1,719.4 39.09 SAPETVVLV CAMCO THEIR 1A SAFETYVALVE 2812 RASUFT', sup 11,529.9 6,689.0 61.87 NIPPLE OTISXSELECTIVE LANDING NIPPLE 2.813 11,5675 6,]06.] 61.89 PBR BAKER PER 3.000 11,561.2 6,)13.1 1.9p PACKER BAKER HB RETRIEVABLE PACKER 2.990 11,597.5 6,7208 6181 NIPPLE OTIS XN NIPPLE NO GO 2.750 11,609.2 6,726.3 61.88 SOS BAKER SHEAR OUTSUB 26992 Other In Role (Wireline retrievable plugs, valves, pumps, fish, etc.) Top IND) I Top Incl Tap("") (%KB) 1 (1) 1 Des Com Run Date IDhn) 11,6820 6,7603 1 61.66 Whipstock Northern Solutions 350-7 O High Expansion Wedge. Set 4.6 degrees ROHS. MRA tag at 11689' (T below top Id HEW). DAL 8,8'M.002.625' 9128(2019 0.000 SURFPCE: OIOG,330,8 Perforations $ Slots sod cos UFT: 11.461 TDp 1%Kal atm pd(e) TeplrvD) (%KBI Bo -n [NDI IaKBI unxedzone Dam Dene lzhdsdt 1 T pe om 111710.0 11,]]0.0 8,]]4.16,803.1 -2,C-1, UNIT B,1R-23 115/1992 10.0 (PERF 14.5 -TT, Go, 60deg ph Prac Summary i.d Gale 011111995 Pmpwnt Designed (to) --r;oRppnn In FermellDn(III NIPPLE: 11.P &lpd SpR Dare TDp Depth Brad BM UUKB) 1 1a11n995 11,]10.It 11,]]0.0 1-hura Fluid System VDI Cup 7Fbll Vol Slurry lbbp Mamlrel Inserts sr in PBR; II,SG]B PPLI(ER; Ii,.y19 up N TDP IRKS) TaplNol Iry1(B) Make Valve Lamh port Sixe TRO Run MWeI OD (int Sery Type Tyw pn) (pzll Run Da@ Co. 1 $250] 24932 CAMCO KBUG- 1 GAS LIFT DMY BK poop 0.0 102]/1992 M 2 11 484.5 6,66].5 OTIS LBD 1112 GAS LIFT DMV RM 0.000 0.0 41111992 Notes: General & Safety NIPPIE: 119P]5 End Cape Annotation IW912010 NOTE'. View Schematic wl Alaska SchemaiL9.a 91192013 NOTE: PROD CSG RKb per RIG DET ARE SHEET SOS', Ii SM3 WNwbak', 11,8920 HPBDnit]ma (PERF;II)m.D1.P PRODUCTION: 282-12, mT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® OCT 30 2019 " OGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑� I Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑sIv Perforate ❑� Other Stimulate El Pull Tubing El Change Approved Program E]Plug for Redrill M Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑' Other: -Whipstock-121 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development D Stratigraphic ❑ Service ❑ 191-101 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-22200-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1R-23 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): _ 10. Field/Pool(s): r ADL 25635, ADL 25636, ADL : I Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12180' 7004' 12178' 7003' 2841 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 123' 123' Surface 6289' 9-5/8" 6331' 4072' Production 12149' 7" 12178' 7003' Perforation Depth MID (ft): Perforation Depth TVD (ft): Tubing Size: 3-1/2" Tubing Grade: J-55 Tubing MD (ft): 11610' 11710'-11770' 6774'-6803' Packers and SSSV Type: Baker HB Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 11581' MD / 6713' TVD 12. Attachments: Proposal Summary ❑� Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/6/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑' GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James-� V I .I -C>T iZt.1C. Contact Name: Ryan McLaughlin Authorized Title: StattC7D-@egineer L. i 2E L- i0 '2 Contact Email: an.mclau hllrl o .COM �7 Contact Phone: 265-6218 -��/ -3Lt. / "�/ Authorized Signature: / � I> Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 Plug Integrity ❑ BOP Test vlll� Mechanical Integrity Test ❑ Location Clearance ❑ Other: I3tjP t�5t fb 35-0c?f-sk -g IMMSO- 7/NOV 0 5 2019 �nnvl�trPr-cv�r+�G�" f to �5-� L25vU ditlS� � p `�' /J APP ratirc:/pa'/ay.Ait�1Sl Post Initial Injection MIT Req'd? Yes ❑ NoD�/ I / f �y f ✓ Spacing Exception Required? Yes ❑ No 0/ Subsequent Form Required: `B _ ¢ O APPROVED BY Approved by: COMMISSIONER THE COMMISSION DaA Lvised 41pP pP � `Atl rrn 10-0 4/2017 A roved a lication is valitl for 12 mon f t e to"B-4B 1013(ltl of Submit Form and Attachments in Duplicate 'w- ConocoPhillips w-ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 30, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to cement squeeze the C -sand erforationss, it out an XN-Nipple, and set a whipstock in the KRU well 1R-23 (PTD# 191-101).a� cl rte%r rryir,%� C e 1R -23L1 (PT Well -work operations are scheduled to begin on 11/6/2019 with CTD operations following in December 2019. The objective will be to drill three laterals KRU 1 R -2;f, 1 R-23PI"01 and 1 R-230-02 targeting the Kuparuk C - sand and A -sand interval.�- ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate the 1 R-23 C -sand perforations utilizing a C -sand cement squeeze via service coil. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 1 R-23 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1R-23 (PTD #191-101) CTD Summary for Sundry Summary of Operations: On October 16th CDR3-AC rigged up and to drill a tri -lateral CTD project. After 3 unsuccessful attempts at drilling the 1R-231-1 lateral, primarily due to hole cleaning issues in the 7" production casing, the decision was made to rig down CDR3-AC from 1 R-23 and set the well up for a cement pilot hole exit and have the rig to come back at a later date and complete the scope of the project under the approved PTD. In preparation for resuming CTD operations on this well, ConocoPhillips Alaska, Inc. hereby submits sundry application to perforate the tubing tail, cement squeeze the C -Sand perforations and 7" casing, mill out the XN nipple in the tubing tail to 2.80" ID, and set a whipstock for future CTD work After a -line and service coil wellwork is complete, CDR3-AC will mill a cement pilot hole, set the 3-1/2" whipstock, and mill a 2.80" window in the production casing at a depth of 11,662' MD. After that, the 1 R-2 PTD GA -9424) delineation lateral will be drilled to the north and crosscut through the C1 and A3 san6§ to determine rock quality and oil -water contact in both sand packages. An anchored billet will be set and the 1 R-23kf-01 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to d&rmine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1 R-23kf 02 (RT V2-T97M) lateral will be drilled to the north, targeting the C1 sands, and lined with 2-3/8" sloAd liner to the tubing tail. Pre -CTD Work 1. RU E -line: Perforate Tubing Tail at 11,590' MD 2. RU CTU: Squeeze cement the C -Sand Perforation, mill out XN-Nipple l(f"ig Work 1 MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 R-230 Lateral (Delineation Lateral A/C Sands - North) Mill cement pilot hole to 11,680' MD b. Set whipstock at 11,662' MD c. Mill 2.80" window at 11,662' MD d. Drill 3" bi-center lateral to TD of 14,975' MD e. Set anchored aluminum billet at 14,100' MD L}- N^(� ! 3. 1 R-23JA-01 Lateral (Delineation Lateral A/C Sands - East) a. Kickoff of the aluminum billet at 14,100' MD P t b. Drill 3" bi-center lateral to TD of 16,520' MD c. Set anchored aluminum billet at 12,500' MD 4. 1 R-231!1 02 Lateral (Cl Sand - North) a. Kickoff of the aluminum billet at 12,500' MD b. Drill 3" bi-center lateral to a TD of 17,000' MD c. Run 2-3/8" slotted/blank liner with oil/water tracer pups and seal bore deployment sleeve from TD up to 11,595' MD 5. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 6. RU E -Line: Set LTP 7. Return well to production. Page 1 of 1 10/30/2019 � L � !§ JY -5;: \/2 w« \ 0 ; J E )! &cli ao§ /) / - \ / § C;\\ \( / Ln/ / \ // ( §§ � L � !§ JY -5;: \/2 w« \; /( 7; \ �/ }\ \; / } D co m zo _ $§ # \ /( \; /( 7; \ �/ }\ \; Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, November 1, 2019 10:51 AM To: McLaughlin, Ryan; Boyer, David L (CED) Cc: Ohlinger, James J Subject: KRU 1R-23(PTD 191-101, Sundry 319-493) Set 2618 Whipstock Ryan, This sundry work for setting a whipstock in motherbore KRU 111-23 has changed from setting a 261B whipstock(originally the C Sand was left open) to a plug for redrill since now all the perforations will be cemented. The paperwork has just increased. This is what is needed: 1. A plug for redrill sundry for KRU 1R-23(PTD 191-101); we can change this existing sundry(319-492) to plug for redrill by hand. No need to resubmit the whipstock sundry. 2. However, the naming convention of the sidetrack and laterals must change as follows and new PTDs must be submitted: a. Well KRU 1R-231_1 will need to be resubmitted as KRU 111-23A b. Well KRU 1R-231-1-01 will need to be resubmitted as KRU 1R -23A-01 c. Well KRU 111-231-1-02 will need to be resubmitted as KRU 1R -23A-02 d. These will all be assigned new PTD and API numbers. The motherbore will be abandoned and the KRU 111-231-1 closed out. I will route the plug for redrill whipstock for KRU 1R-23 for approval today or Monday. However, please submit the required new PTDs. vi So sorry for the additional paperwork. Let me know if any clarification is needed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aoalaska. goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Vic 101 ci,Lroo 0 a alaska oov Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, October 29, 2019 10:18 AM To: McLaughlin, Ryan Cc: Ohlinger, James J Subject: KRU 1 R-23L1(PTD 219-128) Operations Shutdown Request Rya n, Verbal approval is granted for the Operations Shutdown for CRD3-AC for KRU 1R-23L1(PTD 219-128). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(a7alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,. so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.LoeooCalaska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, October 29, 2019 10:13 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: 111-23 (PTD 191-101) Operations Shutdown Request Hello Victoria On October 16th CDR3-AC rigged up to drill a tri -lateral project on 111-23. After 3 unsuccessful attempts at drilling the 111-231-1 lateral, primarily due to hole cleaning issues in the 7" production casing, the decision was made to rig down CDR3-AC from IR -23 and set the well up for a cement pilot hole exit for the rig to come back at a later date and complete the scope of the project under the approved PTD. In preparation for resuming CTD operations on this well, perforations will be shot in the tubing tail, cement will be pumped to occupy the 7" casing and plug off C -sand perforations, and the XN nipple in the tubing tail will be milled out. CDR3-AC will mill a cement pilot hole, set a 3-1/2" whipstock, and mill a 2.80" window in the production casing at a depth of 11,662' MD and complete the original scope of the project under the existing permits . We are requesting verbal approval for an Operations Shutdown with the Sundry to be submitted today. We will also submit a subsequent sundry request for cement -squeezing the C -sand perforations and setting a new whipstock prior to beginning the service coil work. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 Loepp, Victoria T (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, October 29, 2019 10:14 AM To: Loepp, Victoria T (CED) Cc: Ohlinger, James J Subject: RE: [EXTERNAL]KRU 1R-23(PTD 191-101); KRU 1R-23L1(PTD 219-128) Operations Shutdown Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, I have sent a request for verbal approval for Operations Shutdown in a separate email. We plan on resuming drilling in December which should fall within the 60 days period. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, October 29, 2019 9:57 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL)KRU IR-23(PTD 191-101); KRU 1R-23L1(PTD 219-128) Operations Shutdown Ryan, KRU 1J-10(201-071) CTD drilling interruption was different. Only +100' out of the window was drilled. In addition, KRU 1J-10 motherbore was planned to be put back on production. For KRU 1R-23L1(PTD 219-128), three plugbacks -1000- 3000' MD per lateral were drilled. These drilling records should be captured under KRU 1R-23L1(PTD 219-128). This is an Operations Shutdown under this PTD. Please submit a 30-403 Sundry for Operations Shutdown approval(20 AAC 25.072(a)). Will drilling be resumed within 60 days? The AOGCC should be notified for verbal approval for an Operations Shutdown with the Sundry to follow imminently. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCrDalaska.00v 9 VVYVYY � LN 1s❑ �W � N� $� mm EL c p l7 m N_ 0 O Z ❑ � � � E ip N i0 � 0 T CO - iN C J y rtl a. '2 '� ❑ N � o d c °� ro ❑ w cE m 2 ❑ w h m m u 76 y10 U ai U O K cS 2 X N N �V kV Nf/J N N (n N 0] GI 8 _ t4 9 VVYVYY � LN 1s❑ �W � N� $� mm EL c p CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or vlctoiio.Lc Liaaloska.aoy From: McLaughlin, Ryan <Ryan McLaughlin@conocophillips.com> Sent: Tuesday, October 29, 2019 9:18 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov> Cc: Ohlinger, James J <Jarnes J Ohlinger@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1R-23(PTD 191-101) CTD Status Hello Victoria, We did mill a window off of a High Expansion Wedge at 11,682' MD and drilled three plugback that were not lined. I've attached a current CTD schematic of progress to date. We will submit a sundry for plugging the C Sand perforations and setting a new whipstock this afternoon, as well as close out the current sundry (319-421) for setting the High Expansion Wedge that is currently in the well. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.Qov> Sent: Tuesday, October 29, 2019 8:27 AM To: McLaughlin, Ryan <Ryan McLaughlin@conocophillips.com> Subject: [EXTERNAL)KRU 1R-23(PTD 191-101) CTD Status Ryan, Was the window milled? Any drilling? If the 7" is cemented, then you will be plugging the C Sand perforations and the sundry will be a plug for redrill. A current status WBS would be useful. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work. (907)793-1247 Victoria. LoeppCa%alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907(793-1247 or victoria Loeoo@alaska oov From: McLaughlin, Ryan <R ran McLaughlin@conocophillips.com> Sent: Monday, October 28, 20191:41 PM To: Loepp, Victoria T (CED) <victoria loepp@alaska.Pov> Subject: RE: [EXTERNAL]KRU 111-23 Operations Shutdown Victoria, I've attached a PDF of the email. Let me know if you have trouble opening. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria loepp@alaska.dov> Sent: Monday, October 28, 20191:35 PM To: McLaughlin, Ryan <Ryan McLautthlin@conocophillips.com> Subject: Re: [EXTERNAL]KRU 1R-23 Operations Shutdown Unable to open attachment. Please resend in different form - Sent from my iPhone On Oct 28, 2019, at 1:12 PM, McLaughlin, Ryan <Ryan McLaul;hlin@conocophil ss.com> wrote: Victoria, We encountered a very similar situation in February of this year where we moved CDR3 off of the well in order to perform some wellwork before making another attempt at drilling the laterals in June. I've attached the email where you stated that a sundry for operations shutdown was not required. Similarly, in our current situation on 1R-23 we are not shutting down operations, we will be moving the CDR3 off the well to prepare it for a different type of window exit, and returning to continue drilling under the approved permits as soon as we can. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 ConocoPhillips Alaska office: 907-265-6218 Cell: 907-444-7886 700 G st, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria I0e0ff_alaska Rov> Sent: Monday, October 28, 2019 11:34 AM To: McLaughlin, Ryan <man.McLaue,hlinpconocophillips.com> Subject: [EXTERNAL]KRU 1R-23 Operations Shutdown Ryan, Please submit a sundry for Operations Shutdown as soon as possible with plans outlined to return to the well. Thanx, Victoria Sent from my iPhone On Oct 28, 2019, at 11:05 AM, McLaughlin, Ryan <Ryan McLaughlineconocophillips com> wrote: Hello Victoria, I would like to give you a quick operations update for 111-23. While drilling the 1R -23L1 lateral, we struggled with hole cleaning issues in the 7" casing above our High Expansion Wedge. After our third unsuccessful attempt at drilling this lateral we made the decision to temporarily suspend rig operations and RDMO to our next well. After rigging off CDR3 from 111-23, we plan on submitting a sundry to perforate the tubing tail with E - line and pump cement in the 7" casing with service coil. This will set us up to return to 111-23 as soon as possible with CDR3 and drill the permitted laterals from a cement pilot hole window exit. Please let me know if you have any questions. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 <mime -attachment> WELL LOG TRANSM17 TAI. ProActive Diagnostic Services, Inc. To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams OCT 0 9 2019 130 West International Airport Road Suite C Anchorage, AK 99518 AOGCC pdsanchorage(a)memorvlog.com 14 -Sep -19 1R-23 CD 50-029-22200-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)246-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEC&MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM haps rreadcasedhole-my,sharepoint,com/personal/diane williams rsadcasedhole cmn,T omrrents,D Drive/Achives/IvlasterYamplateFlles emplates/DistdbutioMt smittalSheets CovocoPhillips_Transmit doex -_�CASED HOLE 1911�?1 31314 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1R-23 Log Date: September 14, 2019 Field: Kuparuk Log No.: 15703 State: Alaska Run No.: 1 API No. 50-029-22200-00 Pipe Description: 3.5 inch 9.3 lb. J-55 EUEABMOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 11,602 Ft. (MD) Pipe Description: 7 inch 26 Ib. L-80 NSCC Top Log Interval 11,602 Ft. (MD) Inspection Type : Corrosive $ Mechanical Damage Inspection COMMENTS: This caliper data is tied into the gamma K1 marker at 11,099 feet per instructions from the procedure. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to range from good to poor condition, with a maximum recorded wall penetration of 70% in a line of pits in joint 193 (6,036 ft). Additional wall penetrations ranging from 20% to 52% wall thickness are recorded in 49 of the 379 joints logged. Recorded damage appears as isolated pitting and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate the 7 inch casing logged appears to be in good condition outside of the perforation interval with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits 70 193 6,036 Ft. (MD) Line of Pits 52 185 5,761 Ft. (MD) Isolated Pitting 43 160 5,003 Ft. (MD) Isolated Pitting 42 197 6,138 Ft. (MD) Isolated Pitting 41 199 6,208 Ft. (MD) 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(c�readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Outside of the perforation interval, no significant wall penetrations (> 17%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Outside of the perforation interval, no significant areas of cross-sectional wall loss (> 3%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. B. Suhanek C. Waldrop J. Condio Field Engineers) Analysts) Witness(es) READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(alreadcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipet 3.5 in (37.7-11,602.0') Well: 1R-23 Pipe 2 7. in (11,602.0'- 11,760.2') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: September 14, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 ? 50 41 1,560 GLM 1 — 3,126 150 4,682 s E E � Z 200 6,219 r c a I O 250 7,767 300 9,316 350 10,854 GLM 2_ 1 11,602 6 11,722 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 6 ■ Perforations Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 12.6 ppf J-55 EUEABMOD 2.992 in. 38 ft. 11,602 ft. _ Penetration (% wall) uu 80 60 40 20 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed (total = 37 329 45 5 0 Damage Configuration (body) 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Nu ber ofjoi smaggsi (total = 109) 64 0 45 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (4:00) GLM 2 (9:00) Bottom of Survey = 371.7 CASED HOLE Body Region Analysis Well: i R-23 Survey Date: September 14, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 12.6 ppf J-55 EUEABMOD _ Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 12.6 ppf J-55 EUEABMOD 2.992 in. 38 ft. 11,602 ft. _ Penetration (% wall) uu 80 60 40 20 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed (total = 37 329 45 5 0 Damage Configuration (body) 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Nu ber ofjoi smaggsi (total = 109) 64 0 45 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (4:00) GLM 2 (9:00) Bottom of Survey = 371.7 --_� CASED _ HOLE Well: iR-23 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. f Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMOD Tubing Joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 38 ft 11,602 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 38 0 0.01 5 2 2.98 Pu 1 41 0 0.02 9 2 2.91 Lt. De osits. 2 71 0 0.02 9 2 2.92 _ Lt. Deposits. 3 102 0 0.03 11 3 2.90 L. Deposits. 4 133 0 0.02 7 2 2.91 Lt. De osits. 5 163 0 0.03 10 4 2.91 Lt. Deposits. 6 195 0 0.03 11 2 2.93 Lt. De osits. 7 226 0 0.02 7 2 2.93 257 0 0.02 8 2 2.91 Lt. E98 288 0 0.03 10 2 2.91 -Deposits. Lt. De osits. 10 319 0 0.03 10 3 2.91 Lt. De osits. 11 350 0 0.03 13 3 2.90 Lt. De osits. 12 381 0 0.03 10 3 2.91 Lt. Deposits. 13 412 0 0.02 9 2 2.92 Lt. Deposits. 14 443 0 0.03 10 5 2.95 15 475 0 0.03 12 2 2.92 Lt. Deposits. 16 505 0 0,03 1 13 3 2.90 Lt. De osits. 17 536 1 0 0.04 17 3 2.91 Shallow Pitting. Lt. De osits. 18 567 0 0.03 13 3 2.92 Lt. Deposits. 19 598 0 0.03 13 4 1 2.92 Lt. Deo i 20 629 0 0.04 17 2 1 2.95 Shallow Pittin . 21 22 23 661 693 722 0 0 0 0.03 0.03 0.03 13 13 13 2 1 3 1 3 2.94 2.91 2.94 LL Deposits. 24 753 0 0.04 15 7 1 2.93 Shallow Pitting. Lt. Deposits. 25 26 784 816 0 0 0.04 1 0.05 16 19 2 4 2.94 2.93 _ _Shallow Pitting. Shallow Pitting. Lt. Deposits. 27 847 1 0 0.03 11 3 2.95 28 879 0 0.03 11 29 910 0 0.03 11 3 2.92 Lt. Deposits. 30 942 0 0.03 10 1 6 2.93 Lt. Deposits. 31 32 3 973 1002 1034 0 0 0 0.03 0.04 006 12 14 4 2 3 2.91 _ 2.95 2.94 Lt. De osits. Isolated Pittin 34 1065 0 0.03 10 3 2.91 Lt. Deposits. 5 1097 0 0.02 7 2 _ Lt. Deposits. 36 1128 0 0.03 12 2 _ _2.92 2.92 1 Lt De osits. 37 1158 0 0.04 15 4 2.9 Shallow Line of Pits. Lt. Deposits, 38 1187 0 0.03 13 -1 2.89 Lt. Deposits. 39 1219 0 0.05 20 3 1 2.92 Isolated Pittin Lt. Deposits. 40 1250 0 0.03 10 3 2.92 Lt. Deposits. 41 1281 0 0.04 14 4 2.94 42 1311 0 0.03. 11 3 2.94 43 1342 0 _ _ 0.04 16 3 2.91 Shallow Pitting. Lt. De osits. 441-& 8 2 2.93 452 46 6 10 2 2 2.94 2.94 472 7 2 2.93 482 9 2 2.92 Lt. De osits.49 I 10 4 2.91 It.. De osits. Penetration Body Metal Loss Body Page 1 ___9CASED HOLE Well: 1R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc point Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMOD Tubing Nom. ID Body Wall Top Depth- 2.992 in. 0.254 in. 38 ft Bottom Depth 11,602 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 50 51 52 1560 1591 1622 0 0 0 0.02 0.03 0.02_ 9 12 9 4 3 4 2.91 2.92 2.92 Lt. Deposits. _ Lt. Deposits. _ Lt. Deposits. 53 1653 0 0.02 9 3 2.94 54 1684 0 0.03 10 4 2.92 Lt. Deposits. 55 1714 1 0 0.03_ 12 2 2.91 Lt. Deposits__ 56 1745 0 0.03 11 3 2.92 57 1776 1 0.04 0.04 14 6 2.91 Lt i s 57.1 1807 0 0.02 6 0 2.92 _ Pup Lt. D osits. 57.2 18150 0 0 2.82 CamcoTRDP-1ASSSV 57.3 1825 0 0.01 6 2 2.97 Pu 58 1833 0 0.022 7 2 2.90 Lt. Deposits. 59 0.03 10 3 2.93 60 1895 1 0 0.03 10 3 2.92 Lt. Deposits. 61 1926 0 0.03 13 5 2.92 Lt. De osits. 62 1957 1 0 0.03 10 3 2.91 Lt. De osits. 63 1986 1 0 0.02 9 2 2.93 Lt. Deposits. 64 2017 4 0 0.04 15 4 2.93 Shallow Pitting. Lt. Deposits, 65 2048 1 0 0.04_ 14 5 2.91 Lt. Deposits. _ 66 2079 1 0.05 0.05 18 4 292 Shall w Pi tin 67 2110 0 0.04 17 2 2.92 rhAlnvv Pittin . Lt. De osits. 68 2140._ 0 0.02 8 4 2.94 69 2171 0 0.03 11 3 2.92 Lt. Deposits. 70 2202 1 0 0.03 12 4 2.90 Lt. Deposits. 71 2232 1 0 0.05 20 2 2.92 Line of Pits. Lt. Deposits. 72 2262 0 0.04 14 3 2.92 Lt. Deposits. 73 2293 0 0.03 12 4 2.91 Lt. Deposits. 74 2323 0 0.02 7 1 2 2.89 Lt. Deposits. 75 2354 0 0.04 16 3 2.89 Shallow Line of Pits. Lt. De cosi . 76 2384 0 0.06 24 4 2.93 Isolated Pittin Lt. Deposits. 77 2415 0 0.08 3 3 2.93 Line of Pits. Lt. Deposits. 78 79 80 2446 2477 2507 0.04 0 0 0.05 0.05 0.06 21 20 23 3 3 3 2.94 2.95 195 _ Line of Pits. Line of Pits. Isolated Pittin 81 82 83 2538 2568 2599 0 0 0 0_05 0.03 0.05 18 11 18 4 4 5 2.94 2.93 2.94 Shallow Pitfing._._ _ _ Shallow Pitting. 84 2629 0 0.03 10 3 2.94 85 86 2660 2691 0 0 0.02 0.02 9 9 2 3 2.96 2.95 7 2723 0 0.02 8 4 2.93 88 2754 0 007 26 4 2.94 Line of Pits. 89 2784 0 0.04 15 3 2.95 Shallow Pitting.__ 90 2816 0 0.02 9 3 2.92 Lt. De osits. 91 2847 0 0.02 9 2 2.93 92 2878 0 0.02 9 3 2.94 93 29Q9 0.05 0,05 18 2 2.93 ShallowPittn 94 2941 0 0.04 15 2 2.95 Shallow Pitting. 95 2972 0 0.03 13 4 2.94 96 3003 0 0.03 11 4 2.95 Penetration Body Metal Loss Body Page 2 �I CASED HOLE Well: 1 R-23 Field: Kuparuk Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMOD joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 36 ft 11,602 ft. Penetration Body Metal Loss Body Page 3 CASED HOLE Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMCD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 38 ft Bottom Depth 1 11,602 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 146 147 148 4559 4591 4622 0 0 0 0.02 0.03 0.03 9 10 11 4 3 4 2.90 2.90 2.91 Lt. Deposits. Lt Deposits Lt. Deposits. 149 4653 0 0.03 11 4 2.88 Lt, Denosits. 150 151 4682 4714 0 0 0.02 0.02 8 9 3 2 2.91 2.90 Lt. sits._ .. Lt. Deposits. 152 4745 0 0.03 11 4 2.90 Lt. Deposits. 153 4776 0 0 13 3 2.92 Lt. Deposits. 154 4808 0 0.04 14 1 2 2.91 _ Lt. Deposits. 155 4839 0 0.05 21 2 2.93 Isolated Pittin Lt. De sits. 156 4871 0 0.03 13 2 2.90 Lt. De osits. 157 4899 0 0.02 7 2 2.92 Lt. De osits. 158 4930 0 0.04 14 3 2.91 Lt. De osits. 159 4961 0.05 0.03 11 2 2.91 Lt. Deposits. 160 4991 1 0.06 0.11 43 6 2.91 Isolated Pittint_ Lt Deposits. 161 5020 0 0.08 30 2 2.92 Line of Pits. Lt. Deposits 162 5052 0 0.02 9 2 2.91 Lt. DeDosits. 163 5083 0 0.02 7 2 2.91 Lt. osits 164_ 5113 0 0.03 12 6 2.90 Lt. Deo its. 165 5143 0 0.03 11 1 2 2.90 1 Lt. De osits. 166 5174 0 0.02F4� .9 167 20 0 0.0 2.91 Lt. De osi s. 168 5237 0 0.042.94 Shallow Pittin . 169 5268 0 0.052.92 Shallow Pittin . Lt. Deposits. 170 5298 0 0.032.91 Lt. Deposits. 171 5329 0 0.042.9_1 Lt. Deposits. 172 5361 0 2.91 LDeposits. 173 5392 0 0.042.90 Lt it .174 5423 0. 42.90 Shallow Pittin . Lt. D its175 5455 0 0.042.91 Shallow Pitting. Lt. Deposits. 176 5486 0 0.03 10 2 2.94 177 5516 0 0.04 14 2 2.92 Lt. De osits. 178 5545 0.04 0.05 19 2 2,91 Shallow Pitting. Lt. Deposits. 179 5577 0 0.04 16 4 2.90 Shallow Pitting. Lt. DepQsijs, 180 5606 0 0.05 21 4 2.88 Isolated Pittiny Lt. Deposits. 181 5638 - 0 0.06 25 Isolated Pittiny 182 _ 5668 0 0.04 15 4 2.93 Shallow Pitting. 183 5697 0 0.02 9 2 292 Lt Der)osits. 184 185 186 5728 5759 5790 0 -_ 0 0 0.08 0.13 0.03 31 52 12 4 3 1 4 2.93 2.91 1 2.91 Line of Pits. Lt. Deo its. Line of Pits. Lt. Deposits. Lt. Deposits. 187 5822 0 0.03 13 1 4 1 2.91 Lt. Deposits. 188 5853 0 0.05 20 3 2.91 Isolated Pittiny Lt. Deposits. 189 5884 _ 0 QQ8 30 3 2.92 Isolated Pittin Lt. Deposits. 190 5914 0 0.04 15 4 2.89 Shallow PitBn . Lt. Deposits. 191 192 5945 5975 0.04 0 0.10 0.03 39 12 2 4 2.91 2.92 Line of Pits. Lt. Deposits.. Lt. De osits. 193 1 6006 0.09 0.18 70 42.90 Line of Pits. Lt. De osits. 194 603 7 0 0.07 26 2 2.93 Line of Pits, 195 1 6067 0 0.08 31 3 2.92 Isolated Pitting, Lt. Deposits. Penetration Body Metal Loss Body Page 4 HOLED Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc_. Joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop ---]_ Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 38 ft Bottom Depth 11,602 ft. iJ Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % FMin. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 196 6098 0.06 0.07 28 2 2.92 Line of Pits. Lt. De osit . 197 6129 0 .11 42 3 2.92 Isolated Pittin Lt. De osits. 198 6159 0.03 1 4 2.91 Lt. Deposits. 199 6189 0 0.10 41 4 2.91 Isolated Pittin Lt. Deposits. 200 6219 0 0.05 21 4 2.91 Isolated Pitting,Lt. D sits. 201 6250 0 0.03 11 5 2.92 Lt. Deposits. 202 6281 0 0.09 34 4 2.91 Line of Pits. Lt. Deposits. 203K6529 0 0.04 16 2_90 Shallow Pittin¢ Lt. Deposits. 204 205 0 _ 0 0.03._ 0.03 11 13 3 2 _ 2.92 2.91 _ Lt Deposits. Lt. Deposits. 2 0 0.03 11 6 2.94 207 0 0.02 2 2.91 Lt. Deposits. 208 0 0.03 12 6 2.94 209 0 0.02 9 3 2.92 Lt. De osits. 210 211 0 0 0.03 0.02 11 9 2 2_ ! 2.93 2.94 212 6591 0 0.03 11 4 2.89 Lt. De osits. 213 214 215 6622 6654 6685 0 0 1 0 0.03 0.02 0.03 10 9 11 3 2 2 .. 2.92 2.92 2.95 Lt. Deposits. Lt. Deposits. .. 216 6716 0 0.02 9 2 2.91 LL De osits. 217 218 219 6748 6779 6810 0 0 0 0.02 0.03 A104 7 12 14 2 5 3 2.92 _' 2.91 2.95 Lt. De osits. __ 220 6842 0 0.02 _,_ 9 2-2.90 Lt. Deposits. 221 22 6873 6902 0 0 0.03 0.02 11 9 4 _� 3 2.95 !. 2.92 Lt. Deposits. 223 6933 0 0.03 11 2 2.92 Lt. De osits. 224 225 6964 6993 0 1 0 0.03 1 0.02 11 8 5 4 _ 2.92 2.90 Lt. Deposits. _ . Lt. Deposits, 226 7024 0 0.03 11 3 2.90 Lt. Deposits. 227 228 229 -7056 7087 7119 00.03 0 0 _ 0.02 0.02 11 9 8 3 3 1 2 2.93_ 2.91 ! 2.92 Lt. Deposits. Lt. Deposits. Lt. Deposits. 230 231 232 7150 7181 7211 0 0 0 Q,03._ 0.03 0.02 13 12 7 2 2 1 1 2.91 _ 2.92 2.92 Lt, Deposits. Lt. Deposits. _ 1 Lt.- Deposits _ 233 7242 0 0.02 9 3 2.94 234 235 236 1 7272 7304 7335 0 0 1 0 0.03 0.03 0.03 13 10 11 2 2 3 2.93 2.93 2.89 Lt Deposits Lt. 237 238 239 7366.03 7396 7428 0 0 0.04 0.05 13 15 21 3 2 2 2.92 2.90 2.93 Lt. osits. Shallow P46 -g. Lt. Deposits. Isolated Pittin Lt. Deposits. 240 7459 0 0.03 13 2 2.91 Lt. De osits. 241 7491 0 0.03 11 3:. 2.89 Lt. Det)osits. 242 7522 0 0.05 19 2 2.92 Shallow Pi 'n . Lt. Deposits. 243 7553 0 0.0 12 3 2.89 Lt. Deposits. 244 7583 0 0,03 11 5 _2.90 Lt Qsits. __.. 245 7613 0 _ _0.03 1 13 1 3 _; 2.91 Lt. De osits._ Penetration Body Metal Loss Body Page 5 CASED HOLE Joint Tabulation Sheet —MV I Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Pipe Description 3.5 in. 12.6 ppf 1-55 EUEABMOD Tt Survey Date: September 14, 2019 Analyst: Waldrop Nom. ID Body Wall 2.992 in. 0.254 in. Top Depth Bottom Depth 38 ft 11,602 ft. Penetration Body Metal Loss Body Page 6 CASED HOLE �MffWell. 1R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc _ Joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Pipe Description 3.5 in 12.6 ppf J-55 EUEABMOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 38 ft Bottom Depth 11,602 ft. Joint jt. No. Depth (Ft.) Pen.Pen. Upset (in.) Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile I% wall) 0 50 100 296 1 0 0.07 26 2 2.92 Line of Pits. Lt. D sits. IF 297 222 0 3 12 3 2.92 Lt. Deposits. 298 9254 0 0.04 15 5 Shallow Line of Pits. Lt. Deposits. 299 9285 1 0 0.02 9 2.91 Lt. De osits. 300 0.04 15 4 2.93 hallow Pittin . It. _Deposits. 3 1 0 0.04 16 3 2.90 Shallow Line of Pits. Lt. Deposits. 3020 0.03 12 3 2.91 Lt. De osits. 303 0 0.03 til 3 2.93 304 t-9 0 0.02 9 4 2.89 Lt. De osits. 305 0 3 12 3 2.89 Lt. osits. 3060 0.04 17 2.90 Shallow Line of Pits. D osits. 3070 0,04 14 2 2.88 Lt. Deposits. 308 9566 0 003 11 4 2.90 Lt. osits. 309 9597 0 0.03 11 4 2.91 It. Deposits. 310 9k26 0 0.03 13 3 2.92 Lt. De sits. 311 9656 0 0.03 11 2 2.90 Lt. Deposits. 12 9688 0.04 0.04 17 4 2.92 Shallow Line of Pits. Lt. D osits 313 9720 0 0.02 9 2 2,94 314 9749 0 0.02 9 3 2.89 1 Lt. De osits. 315 9781 0 0.03 11 5 2.93 Lt. De o ' 316 9811 1 0 0.02 7 2 2.89 Lt. De osit . 9840 0 0.03 12 3 2.89 Lt. De o f s. 9872 0 0.03 11 3 2.88 Lt. Deposits. 900 0 0.03 10 3 2.89 Lt. Deposits. 9931 0.02 9 2 2.88 Lt. sits. F32 9964 0 0.03 11 5 2.93 9995 0 004 14 4 2.93 L . De osits. 10025 0 0.02 9 3 2.9 L . De osits. 10057 0 002 7 2 1 2.91 Lt De osits. 325 10089 _ 0 0.05 1 20 3 2.91 Line Corrosion. Lt. De sill 326 10120 0 0.03 10 3 2.92 Lt. Dei)osits. 327 10150 0 0.04 14 . 2 It De o i s. 328 10179 0 0.03 13 2 2.89 Lt. De osits. 329 10211 0.05 0.03 11 3 .89 Lt. De osits. 330 10240 0 0.02 9 3 2.92 sits. _ 331 0 0.04 16 4 2.91 Shallow Line of Pits. Lt. D osits. 332 _10269 10300 0 0.05 20 3 289 Line Corrosion. It De sits. 3 10331 0 0.03 11 3 2.91 Lt. De osits. 334 10363 0 0.02 9 3 92 L. De osits. 335 10394 0 03 10 2 2.91 Lt. De osits. 336 10425 1 0 7 26 2.89 1 Line Corrosion. Lt. Deposits. 337 1 454 0 .03 13 3 2.90 Lt. DeDosits. 33810486 0 0.05 20 3 2.91 Line Corrosion Lt. Deposits. 339 70517 0.04 0.02 8 2 2.90 Lt. Deposits. 340 10546 0 0.02 7 2 2.91 Lt Deposits. 41 0575 0 0.03 13 3 2,92 Lt Deposits. 342 10605 0 0.03 11 2 2.91 Lt. De osits. 343 10636 0 0. 73 2 2.88 Lt. De osits. 344 1 0 0.03 10 2 .92 Lt. De off. 345 10699 0 0.03 11 2 2.91 Lt. Deposits. Penetration Body Metal Loss Body Page 7 CASED HOLE Well: iR-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc _ Pipe Description 3.5 in. 12.6 ppf J-55 EUEABMOD Tubing Joint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 38 ft 11,602 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (%wall) 0 50 100 3 1 731 0 .03 11 3 2.89 Lt. .posits 47 10759 0 0.05 18 4 2.89 Shallow Pits-. Lt. Deoosi . 348 1 791 0 0.02 9 3 1 2.92 Lt. De osits. 349 10822 0 3 .88 Lt. Deposits. 350 10854 4 2.90 Shallow Pitlin . Lt. De i . 351 10886 0 2 2.90 Lt. Deposits. 352 10918 0 3 2.91 Lt. De osits. 353 10947 0 ;O�E041 3 2.89 Lt. De osits. 354 10979 0 4 2.87 Line Corrosion. Lt. Deposits. 355 11008 0 3 2. 0 Shallow Lin of Pits. Lt. D osits. 356 11039 0 3 1 Lt. De osits. 357 11 0 4 2.90 hallow Line Corrosion. LL Deoosits. 358 11097 0 1 0.03 12 2 2.92 Lt. Deposits. 359 11128 0 0.05 19 1 2 2.91 Shallow Line Corrosion. Lt. Deposits. 36_0_ 11160 0.04 0.02 9 2 2.93 Lt. Deposits. 361 11190 0 0.03 12 2 2.88 Lt. Deposits. 362 11222 0 0.05 20 4 2.92 Line Corrosion. Lt. Deposits. 363 11254 0 0. 10 2 2.89 L. Denosits. 364 11286 0 0.03 13 3 2.90 Lt. Deposits. 365 11318 0 0.03 11 2 2.89 Lt. De osits. 366 11347 0 0.02 9 2 2.90 Lt. De osits. 367 11379 '�. 0 0.02 9 2 2.91 Lt. De osits. 368 11408,_ 0 0.03 10 3 2.91 Lt. Deposits. 369 11439 0 0.05 1 19 6 2.91 Shall w Lin f Pits. Lt. Deposits. 69.1 11471 0 0.03 1 11 2 291 Pup Lt. Deposits. 369.2_ 11478 0 0 0 2:84 GLM 2 La[ch @ 9:00 369.3 11486 0 0.01 2 2.92 Pu Lt. D osits. 370 11492 I 0 0.03 10 3 2.94 370.1 11522 0 0 0 2.81 i XLandin Nipple 371 11524 0 O.Q3 13 4 Lt. De osits. 371.1 11554 0 0. 1 6 2 2.9 Pu 371. 11560 0 0 0 0 Seal Assembly 371.3 11573 0 0 0 0 2.87 Baker HB Retrievable Packer 71.4 11580 0 0.03 13 2 2.94 Pu 371.5 11590 0 0 2.82 Otis XN Nipple 371.6 11591 0 0.02 9 2.88 Pup Lt. De osits. 371.7 1.1602._ 0 0 1 0 1 0 1 2.97 WLEG 'Penetration Body Metal Loss Body Page 8 CASED HOLE Cross-sectional Illustration Survey Date: September 14, 2019 Tool Type: Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubine: 3.5 in. 12.6 opf 1-55 EUD Cross-sectional Illustration Survey Date: September 14, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 193 at depth 6,036.370 ft. Tool speed = 51 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 59° Finger = 11 Penetration = 0.177 in. —M= September 14, 2019 CASED UW MFC 24 Ext. No. 218183 Tool Size: HOLE Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA T,d.in I; in 19 A nnf I_SS FI IFARAAnn Cross-sectional Illustration Survey Date: September 14, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 185 at depth 5,760.640 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 97% Tool deviation = 56° Finger = 23 Penetration = 0.132 in. Line of Pits 0.13 in.= 52% Wall Penetration HIGH SIDE = UP == CASED �- HOLE Body Region Analysis Well: 1R-23 Survey Date: September 14, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf L-80 NSCC Analyst Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26p ff L-80 NSCC 6.276 in. 11,602 ft. 11,760 ft. 10 8 6 4 2 0 10 8 6 Penetration (% wall) 0 to 20 to 40 to over 20% 40% 85% 85% Numr of joints analyzed (total = 6) 4 0 0 0 Damage Configuration (body) 4 2 — � i I --J 0 . Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 2 3 4 5 i 6 Bottom of Survey = 6 Perforations CASED HOLE Well: 1 R-23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc loint Tabulation Sheet Survey Date: September 14, 2019 Analyst: Waldrop Pipe Description 7 in 26 ppf L-80 NSCC Casing Nom. ID Body Wall Top Depth 6.276 in. 0.362 in. 11,602 ft. BottomDepth 11,760 ft. Joint No. Jt. DepthPen. (Ft.) t Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Comments Damage Profile (% wall) I 0 50 100 1 0.06 17 1 6.05 Shallow Line rrosion. Lt. D osits. 2 . 5 13 2 6. 4 Lt. De osits. Ej 0.06 16 3 6.21 Shallow Lin orrosion. L . De osits. 4 0.05 12 2 6.16 Lt. De osits. 0.4 1 16 6.1 6 11722 0.38 100 13 5.99 Perforations Lt Deposits. 'Penetration Perforations Metal Loss Perforations Page 1 Penetration Body Metal Loss Body ✓AilKUP INJ IR -23 ConocoPhllllp5 lWell Attributes Max Anglo TD A 3ska.lnc. weneort APulm9 F1elaPARUN.m6 w.unon amus 50029240000 KUK R IVER UNIT INJ ncl l•) MD(W.) nn Blm tnk6l 66.10 3.000.00 121800 ommeM N281Ppn1 Bala TROP ombn En4b9 WO: 116/192SSSV: KBL141nMs1w19A81Y 42.9BIB B0aI2e1 tRi].1L3MD1S a:1s:n PM eKB) EM BeM Last Tag�SLM 11,6920 8/9Y2015 noletien Lu1M Y E IM Rev Reaapn: PULLED FRAC SLEEVE Ie6BIlI 12/3012015 Cuing Strings C inn ODllnl IOlinl TWI 1 aN 9d 1 1... n .., r10,T","". oP ED CONDUCTOR 16 15.062 440 123.0 123.0 62.W H-00 WELDEO xAUBEB: asa Igprwngwn oo 1131 IBIIn) Taplrtnel aN Bepn O.M sa Begn 4,22 wpL3 00 J-55 T O SUflFACE 9518 8921 420 6.330.0 4,0]2.4 38.00 J-55 TO iy mr NI1"""'Iml w 1 SM n 1 Dean 1... 1 w PRODUCTION n ] 6.46 291 12 17'7 ],0@S 26.000 L-80 NSCC Tubing Strings u Ina Deacrip6on TUBING w0 sln,q lin TOPIBKBI .1 DeM ln.. sel oe (rvD (... wlllwr crane ovconllectwn 31rz 2.992 38.3 11.609.9 6.]26] 9.30 J-55 EUEABMOD Cornpledon Details Nomn tapinNioP (1VBI 83Tepl 1 Imm Dn Can 1131) CCNBDCTgy a.B-0aaD 38.3 38S83 00001HANGER FMCGENIVTUBISAFEN 3.500 38 1. 18.0 1,719.4 39.09 SAFETY VLV CAMCO TRDP-0A SAFETY VAA LVE 2812 11,529.9 6,6 .0 61.87 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 1,56].5 .) .89 POP BAKER PM T581.2 ,] —61 90 PA K R BAKER HB RETRIEVABLE PKE SPFE(V VLV;tAta.O 1 1,59>5 61.91 NIPPLE OTIS %N NIPPLE NO GO 2350 11,6(t9.2 6,728.3 61.88 SOS BAKER SHEAR OUT SUB 2.992 Perforations a Slots SMI Dena a+SufT: a]6o.T Ban TCPIND) &an M14 att Ty n 1IMI , 5,1dI .B) 031 . C-2CEo-1P,e 11511D9w92 0. IP SCp Gucna; dePaTOP1K10 UNIT B. iR- 23 Stimulations & Treatments Mtn Top MaxBM o,nii MKB) CepIF INKS) T3PITVBI DD®1 oni DV➢) B1KB1 T. DN Com 0 11,]]0. . ,80.1 HPBO Q'1 / UM 1 9M F OSAND AND ,4 F ,71 ,]] 5 ROCK SALT. INITIAL ISIP 2780 PSI, FINAL ISIP 2)14PSI. Mandrel Inserts Bt .I BUBFPCE:4a,pa,9be� TOP]RDI N T-PvmoI mor Ma'M MCMI Wlln) Port SW Typ I. VslreH.;= -. T. Run (pan Bun Ma Ceal 3,25071 2,493.2 CAM KBUG-lux-, LIF M1 0 i ]/ M 2 1 d S 6.66>.6 OTIS LRD 1112 GA LIFT DMY RM 0.000 p 41111992 Notes: General 8 Safety End 0. Anmmien . UFR.UANS 1 1 Mu TE: New Mnt&!,C w/ AlaSkB CII M . 911 TE'. PROD RM per RIG DETAIL SHEET NIPp"E, 11,6309 GBB; 11,m) 8 PACtER; 11681] NIWLE:11,g1.6 SOS: 116Y9.3 HPBD:11,]10.0 II£PF; n2+4o-11,nB4 PROpuLlldi: R.z-12111 T THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-23 Permit to Drill Number: 191-101 Sundry Number: 319-421 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �^ tsie L. Chmielowski Commissioner DATED this ) ? day of September, 2019. RBDMS �� ✓"SEP 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �c I 0 0GC.'4C, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[-] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑� Other: —Whipstock—El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ . 191-101 3. Address: 6. API Number: L2-2-00 ,7A PO Box 100360, Anchorage AK 99510 50-0292711 9 0-00 S9, 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 R-23 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): (j7jj„z6� 1-1 10. Field/Pool(s): L 25%, ADL 25627, FttY 2660 Kupamk River Field / Kuparuk Oil Pool - 11. , (4 1'PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12180' - 7004' 12178' 7003' 2841 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 123' 123' Surface 6289' 9-5/8" 6331' 4072' Production 12149' 7" 12178' 7003' Perforation Depth MD (ft): IPerforation Depth TVD (ft):Tubing Size: 3-1/2" Tubing Grade: J-55 Tubing MD (ft): 11610' 11710'-11770' 6774'-6803' Packers and SSSV Type: Baker HB Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 11 581'MD / 6713' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/19/2019 OIL ❑ WINJ ❑� WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Ryan McLaughlin Authorized Title: Staff CTD Engineer Contact Email: an.mclaU hlln(akO .com ,� Contact Phone: 265-6218 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP fl5 f f) 3,500 tp1s-�S vlar 1)/—�VlV1Jt✓ flSt jo 250o i>`' q J P -/SEP iYes Post Initial Injection MIT Req'd? ❑ No RBDMS 1 9 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by:(__ COMMISSIONER THE COMMISSION Date: v7Z 9�iB/i 9 ORIGINAL s�> �I 801nz> Ts L Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachment rn Du I :ate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 12, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to mill out an XN nipple and set a High Expansion Wedge in KRU 1R-23 (PTD #191-101) in order to drill three CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. I — Attached to this application are the following documents: - 10-403 Sundry Application for KRU IR -23 - Operations Summary in support of the 10-403 sundry application - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1R-23 (PTD #191-101) CTD Summary for Sundry Summary of Operations: KRU well 1 R-23 is an injector equipped with 3-1/2" tubing and 7" production casing. In preparation for CTD operations on this well, the XN nipple will have to be milled out and a high expansion wedge will ✓ be set pre -rig. CDR3-AC will mill a 2.80" window in the production casing at a depth of 11,680' MD. After that, the 1 R- 231-1 delineation lateral will be drilled to the north and crosscut through the C1 and A3 sands to determine rock quality and oil -water contact in both sand packages. A anchored billet will be set and the 1 R -23L1-01 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to determine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1R-231_1-02 lateral will be drilled to the north, targeting the C1 sands, and lined with 2-3/8" slotted liner to the tubing tail. Pre -CTD Work 4. 'IR -231-1-02 Lateral (Cl Sand— North) a. Kick off of the aluminum billet at 12,500' MD b. Drill 3" bi-center lateral to a TD of 17,000' MD c. Run 2-3/8" slotted/blank liner with oil/water tracer pups and sealbore deployment sleeve from TD up to 11,595' MD 5. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 6. RU E -Line: Set LTP 7. Return well to production. Page 1 of 1 9/12/2019 1. RU Slickline: Dummy whipstock drift, SBHP 2. RU E -line: Caliper 3. RU CTU: Mill D-Nipple J 4. RU E -Line: Set High Expansion Wedge yy� 5 Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 R -23L1 Lateral (Delineation Lateral A/C Sands - North) a Mill 2.80" window at 11,680' MD b. Drill 3" bi-center lateral to TD of 14,975' MD vJ c. Set anchored aluminum billet at 14,100' MD Q 3. 1 R-231-1-01 Lateral (Delineation Lateral A/C Sands - East) V a. Kickoff of the aluminum billet at 14,100' MD b. Drill 3" bi-center lateral to TD of 16,520' MD c. Set anchored aluminum billet at 12,500' MD 4. 'IR -231-1-02 Lateral (Cl Sand— North) a. Kick off of the aluminum billet at 12,500' MD b. Drill 3" bi-center lateral to a TD of 17,000' MD c. Run 2-3/8" slotted/blank liner with oil/water tracer pups and sealbore deployment sleeve from TD up to 11,595' MD 5. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 6. RU E -Line: Set LTP 7. Return well to production. Page 1 of 1 9/12/2019 1R-23 Proposed CTD Schematic 16" 62# H-40 shoe @123'MID 9-5/8" 36# J-55 shoe @ 6331' MD KOP @ 11,680' MD via 7" HEW Cps 11,7 70' MID 7.126# L-80 shoe @ 12,178' MD 3-1/2 Carrico TRDP-1A SSSV at 1816' MD 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco gas lift mandrel at 3251' 3-1/2" OTIS gas lift mandrel at 11,485' OTIS X Selective landing nipple @ 11,530' MD (2.813" ID) Baker 3-1/2" PBR at 11,568' MD Baker HB packer at 11,581' MD (2.89" ID) OTIS XN-nipple at 11,598' MD (2.75" min ID, No -Go) 3-1/2" SOS at 11,609' MD 1 R-231.1-02 wp02 TD @ 17,000' MD Top of Liner @ 11.605' MD 1R-23Li-D1 wp03 TD @ 16,520' MD OiIS Weter Tracerm Pups OH -Anchor elllel @ 12,509 MD IR -231-1 "02 TD 0 14,975' MD OH-Airi mr aiilet a 14.109 MO KUP [NJ WELLNAME 1R-23 WELLBORE 1R-23 CCo (nJoc�(oP Well Attributes Max AngleBMD TD ------- -'"11� tlNeme weC.-APUUW 'miWe5blus dl') MD Liken ACI..UnkBI Alaska, Inc KU PARUH RIVER UNIT 500292220000 INT 8.10 3,00000 121800 ISSSV:TRDP 172-H, B'18'X119I'.a95)PM Last Tag VasalsNvren(xeall AnnotaYon DEme RULE) EM Dan We1Rore Iasi Men By Last Tag: SLM 11,692.0 BNRO15 lin" ilemene .- . ............_... _............... Last Rev Reason Annotann Ilne bin wmlwa Las MM By Rev Reason: PULLED FRAC SLEEVE 12130/2015 tR-2J leh" W OER; H3 Casing Strings cONDDescription oo (inI m(n rop nnBl sH Cepm genal eet cepin lrvoL.. wvLen p... G use Tap Tlneatl CONDUCTOR 16 15.06 d4.0 1230 1230 62.50 H<0 WELDED Qang Description ID(mt Top mkBl semimmemm RI BN Depin(NDL.. wulan IL.Gutle rop Tneaa ILL.SURFACE JUST., 9518 892 420 6,330.8 4,0724 36.00 J-55 BTC Caalna DeaalpGao OD(in) IDM) TOPINAU) Set Bron FIRD BN Deem (FVUe IT Top Tme" PRODUCTION 7 628 29.2 12,1)7,) 7,002.5 jWMeA 131om 26.00 L-80 NSCC co6DperaR:«p1H0 Tubing Strings Tubing Description siMg Ma... IBIIn) TOPInK D SM Depen n.. se Deem ttvD11... w111bn1 Outle Top cnnnecron TUBING WO 3112 2.99 38.3 11,609.9 6,726) 930 J-55 EUEASMOD Completion Details Top DVD) ToPmtl Nominal SAFETYKN, Lm.0 Top InKB) (nKR) (•I Ilem Des core IB (in) 38.3 383 001 HANGER FMC GEN IV TUBING HANGER 3.500 1,816.0 1,7194 39.09 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 11,529.9 6,689.0 6.87 NIPPLE OTISX SELECTIVE LANDING NIPPLE 2.813 11,56).5 6706.7 61.89 TBR BAKER PBR 3.000 WiLIFT: S,YA.716 11,581.2 8713.1 61.90 PACKER BAKER HIS RETRIEVABLE PACKER 2890 11,597.5 6 72T 61.91 NIPPLE OTIS XN NIPPLE NO GO 2.750 116092 67263 61,88 SOS BAKER SHEAR OUT SUB 2992 Perforations S Slots Sabi D ria Top(NB) Blm (rvB) pnoisNi 41171.. nnB) InNB) (2It8) LInkM2me Dan I Type Com1])00 6.))4.1 6803.1 -1. UNir 1/5/1992 00IPERF 4.S- Csg Gun; 601 leg ph I B,1R-23 I SURFACE, 42Le,AN.e Frac Summary smart Date Emerging Desgreape) Pmppeneln Pormamnln) 10/11/1995 $Ua Start Dan Top DepasFroa) . naki) Llnkn FWtl Syatam VOICIun(titi9 MOISIary(bi) 1 10I11I1995 117100 11770.0 Mandrel Inserts GAS LIFT 11 nA5 in an on p DV N Top MIKE)ToFrBD) Make Morel COIn) goes 1 Vase Union Task Time,1 Pennine I T(bank (bankan Run Dave Co. 1 3250) 2d932 CA AC0 KBU - 1 GAS LIFT DMY BK 0.000 0.0 10f2➢1992 M NIGGLE: 11.5288 2 11,484.5 fifi6).5 DTI$ LBO 1l/2 GASLIFT DMY RM 0.000 00 4/1/1992 Notes: General & Safety End Dan I Annonnon 10/19/2010 INOTE'. V2w Scnemalic w) Alaska Scnema1i190 9/19/2013 I.LTTE'. PROD CSG RKB per RIG DETAIL SHEET PBR; 11,58]8 RESUME, 115913 NIPPLE', 11SID 5 606: 116B3i FP.D 1.7100 ))) IPERF: 11.]100.10O11.]720 PRODUCTION, 29? 2,11]7) C Loepp, Victoria T (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Wednesday, September 18, 2019 10:43 AM To: Lci Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 R-23(PTD 191-101, Sundry 319-421) Whipstock; BOP test pressure BOP test pressure will be 3500 psi Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G 5t, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 18, 2019 9:51 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1R-23(PTD 191-101, Sundry 319-421) Whipstock; BOP test pressure Ryan, What is BOP test pressure for drilling the laterals? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppA a laska. aov CONFIDENTIAM NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loegp@alaska.aov Davies, Stephen F (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Monday, September 16, 2019 11:18 AM To: Davies, Stephen F (CED) Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Steve, That is correct. The high expansion wedge is non -isolating. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Monday, September 16, 2019 11:16 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Ryan, Could you please confirm that the proposed High Expansion Wedge will not isolate the existing C -sand perforations in KRU SR -23? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.¢ov. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Monday, May 20, 2019 TO: Jim Regg P.I. Supervisor p� S(%/ZI (� SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA, INC. IA IR -23 FROM: Adam Earl KUPARUK RIV UNIT IR -23 Petroleum Inspector 1860 - 1355 Ste: Inspector 320 Reviewed By: 380 - P.I. Supry J13P-- 380 �— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR -23 Insp Now mitAGE190510092359 Rel Insp Num: Well IR 23 !Type Inj PTD 1911010 'Type Te: BBL Pumped. 13 �Bl Interval 4YRTST Notes: MIT IA API Well Number 50-029-22200-00-00 Permit Number: 191-101-0 Packer Depth w 1TVD I 6712 Tubing SPT ITeSt psi _ 1678 IA Returned: 12 OA P/F P� Inspector Name: Adam Earl Inspection Date: 5/8/2019 Pretest Initial 15 Min 30 Min a5 Min 60 Agin Monday, May 20, 2019 Page I of 1 2420 2410 ' 2425 >J'> - 1390 1905 - 1860 - 1355 320 380 - 380 380 �— Monday, May 20, 2019 Page I of 1 STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COMMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I— Plug Perforations Fracture Stimulate Pull Tubing IT Operations Shutdown Performed: Suspend IT Perforate I— Other Stimulate I— Alter Casing IT Change Approved Program Plug for Redrill I— Perforate New Pool IT Repair Well I Re-enter Susp Well I . HPBD P- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r- 191-101 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ', Service 50-029-22200-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25636 KRU 1 R-23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12180 feet Plugs(measured) None true vertical 7004 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 11581 true vertical 0 feet (true vertical) 6713 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 123 123 0 0 SURFACE 6289 9 5/8 6331 4072 0 0 PRODUCTION 12149 7 12178 7003 0 0 $CAWNEPl p;::', 9' Perforation depth: Measured depth: 11710-11770 i ?Y True Vertical Depth: 6774-6803 )AN 2C r?j;t Tubing(size,grade,MD,and ND) 3.5,J-55, 11609 MD, 6726 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HB RETRIEVABLE PACKER @ 11581 MD and 6713 ND SAFETY VLV-CAMCO TRDP-1A SAFETY VALVE @ 1816 MD and 1719 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 700 750 2180 Subsequent to operation 0 0 2070 1500 2424 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory I •••••. Development IT Service 1', Stratigraphic I- Copies of Logs and Surveys Run r 16.Well Status after work: Oil IT Gas r WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR T WINJ } WAG T GINJ r SUSP SPLUG IT 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-608 Contact Mike Hazen@,265-1032 Email Michael.C.Hazen(a.conocophillios.com Printed Name Mike en Title Staff Wells Engineer / Signature — ��� Phone: 265-1032 Date 2014N Ip V'TL 2/ 11 /R3DMS Form 10-404 Revised 5/2015 /��� 1,V JAN 2 1 1016 Submit Original Only KUP � 1 R-23 ConocoPhillips Well Attribut Max Angle D TD • A1i;1Ska Inc, Wellbore API/UWI Field Name Wellbore Status not(°) MD(ftKB) Act Btm(ftKB) Can0079119999 500292220000 KUPARUK RIVER UNIT INJ 66.10 3,000.00 12,180.0 ... `.a Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1R-23,1/12/20169:51'.10 AM SSSV:TRDP Last WO' 1/6/1992 42.99 10/27/1991 - .......Vertical schematic(acral) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11,692.0 8/9/2015 Rev Reason:PULLED FRAC SLEEVE lehallf 12/30/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 44.0 123.0 123.0 62.50 H-40 WELDED HANGER;38.3 �; Casing Description SOD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 42.0 6,330.8 4,072.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.2 12,177.7 7,002.5 26.00 L-80 NSCC ;"Tubing Strings ' Tubing DescriptionID(in)String Ma... Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO Description ! 3 1/21 2.9921 38.31 11,609.91 6,726 .71 9.301 J- 55 I EUEABMOD • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I') Item Des Com (in) CONDUCTOR;44.0-123.5 38.3 38.3 0.01 HANGER FMC GEN IV TUBING HANGER 3.500 1,816.0 1,719.4 39.09 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 11,529.9 6,689.0 61.87 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 11,567.5 6,706.7 61.89 PBR BAKER PBR 3.000 11,581.2 6,713.1 61.90 PACKER BAKER HB RETRIEVABLE PACKER 2.890 SAFETY VLV;1,816 0 11,597.5 6,720.8 61.91 NIPPLE OTIS XN NIPPLE NO GO 2.750 11,609.2 6,726.3 61.88 SOS BAKER SHEAR OUT SUB 2.992 Perforations&Slots shot Dens GAS LIFT;3,250.7 Top(TVD) Bim(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) . (MB) Zone Date ft) Type Com 11,710.0 11,770.0 6,774.1 6,803.1 C-2,C-1, 1/5/1992 10.0 (PERF 4.5"Csg Gun;60 deg ph UNIT B,1R- 23 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (MB) (ftKB) Type Date Com 11,710.0 11,770.0 6,774.1 6,803.1 HPBD 10/11/199 PUMP 12,0698 OF 20/40 SAND AND 2,4908 OF 5 ROCK SALT. INITIAL ISIP 2780 PSI,FINAL ISIP 2714 PSI. Mandrel Inserts St ---- --. ._ ati on Top(ND) Valve Latch Port Size TRO Run SURFACE;42.0-6,3308 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,250.7 2,493.2 CAMCO KBUG- 1'GAS LIFT DMY BK 0.000 0.0 10/27/1992 M 2 11,484.5 6,667.5 OTIS LBD 1 1/2 GAS LIFT DMY RM 0.000 0.0 4/1/1992 Notes:General&Safety GAS LIFT 11,484 5 End Date Annotation 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 9/19/2013 NOTE:PROD CSG RKB per RIG DETAIL SHEET li NIPPLE,11,529.9 I/ W PBR;11,567.6 .,M..J PACKER;11,581.3 NIPPLE,11,597.5 I SOS,11,609.2 it HPBD;11,710.0 (PERF;11,710.0-11,770.0 �— PRODUCTION;29.2-12,177.7 4 d 1 R-23 • DTTM JOBTYP SUMMARYOPS START 12/22/15 FRACTURING COMPLETED HPBD, PUMPED TOTAL OF 17,980#20/40 SAND DURING SCOUR STAGES AND 4600#OF ROCK SALT FOR DIVERSION STAGES WITH A MAXIMUM 27 BPM @ 6000 PSI. PRESSURE RESPONSE SEEN ON LAST OVER FLUSH, WELL IS FREEZE PROTECTED WITH 20 DIESEL. 12/23/15 PUMPING PUMP 21BBLS DSL DOWN TBG, ( JOB COMPLETE ) TRACKING ONLY 12/28/15 FRACTURING PULLED FRAC. SLEEVE @ 1816' RKB. JOB COMPLETE. • 0 En c (f) E E cr: 0 0 L, 06 >s •- 0 0) N- LU o N co in Ln co rn o N- m N- i o- o- LU w E c C -O co 00 0 0 0 0 0 0 O (V '= •5 06 rn co o 0 0 0 0 0 0 E � + L� E L. T X i C L O — oc o N UaoC•I CO CV � � � r-- 0 GG C - CO op N- LOMLO m � � trt3 7' Ln Oi o 0 0 0 0 0 V CCS 0) Na C ° o 0 C,„,, U .1/.��1r O \V f,1. a ci L L SVd 0N m r r L 0Eti <CI) q °? 17- O � m Z 0 co v O 0 0 U U) o N- N rn N L SS C Q Q LU L CO Zco CO CO ,- CO CO .1.1 en Cl) L co W ^+ co aj-0d N a >, co C cn m 3 m o 75 c a@ r O «) tti - O c 0 co O O M O L n C-- 0 c X m E a ,- c- - . O SiO N O O M N- LI) CU CO o Q. 0 CD (I) o i ' Co Co Q Z I-- I-- -cn E W o E,7 E @ N N d. 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O L 0 �O Q >,U O p E U -F) O U L 0 0 E N(h U .� N Q E C o x _O_ co OU = U >, 'O CIO) OC E CV p E N U L' 'Cl U 0-O 0 0- U C w O 0 00 U co .0 O N.� > U U U U 0 U) o O U0 _' C a O O -O CnC1 E N T- CN U U -0 E -O C O.- C Z O -t .0 U C C 0 I2 E C N 0 0 C > U C 0) C L 0) U ) U N U (n Q U N O 0 d = U C U U o U E O O 0 L- a —O` U N Q N C _ 2 U0.‘n g N U U Q Q U U U U a • c 0-- -O O IL O U �O U U _N 7 O C O C O U C— a.. On,'rn U O U a U rn Un UE. 6 N U 0 U O ,, U 0 U 0 0U 'O O 0_ E _a Ti 0 .- E U > x "O U EE O U co U a_ U U C C L U 0 O C O O d 0 U7:3 O C E m > o 7 9 U (.0 TD u, 0E >-- 'O 8 • C U O — C U N � E :2 CT) TO O ip- O C U .-; Z o Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, August 13, 2015 11:51 AM To: 'Nelson, Tim J' Cc: Wallace, Chris D (DOA) Subject: RE: 1R HPBDs (1R-23 PTD 191-101 and 1R-36 PTD 201-227) Gelled LVT Tim, Revised pump schedule is approved for the HBPD on 1R-23 and 1R-36. Gelled LVT is acceptable carrier for placing diversion rock salt. A copy of this email will be placed in both well files. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office ���r` pI(lI(r, nn CONFIDENTIALITY NOTICE:This e-mail message,including any ai4 ,Por4 [s irifahlatkIFI from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Nelson, Tim J [mailto:Timothy.J.Nelson@conocophillips.com] Sent: Wednesday, August 12, 2015 3:23 PM To: Schwartz, Guy L (DOA) Subject: 1R HPBDs Guy, I thought I sent this to you before (bad memory and I can't find it in my sent emails or a reply from you)so disregard if I did. Per our conversation of several weeks ago please see the attached revised pump schedules for 1R-23 and 1R-36 HPBDs. Also attached are the original approved sundries. Please indicate you concurrence with the proposed changes. Thanks Tim Nelson 1 • N M�%b � o o * oo oo T T o r m v D m 1 g OM M00.- AO• • W Z C D .� p N of A W N + O O W V Q G A N N it --I Q N it itiQ Z 3c• 13 N (D 0 C O .� OW 0 D < Q O p m o o cn cairn o O m m 7. o) o c o 00 x 0�_ O 0 0) O 0) 0 C N N n MO r.N• CT c c n3 Cr 0 a F. m la m D.m m = 30 0 7 a 7e m O _ Q O w 7 m c y Cr tl' n O +: O N 0 -• N 0 N 0 -•4, A w 3 S $ D • 3 N 0 O N CO 3 D O G O I� Z O c m 7 v o m 0 "3 (1n CD 3 C % D z n n v 3 i r v m A O r+ ri w m O r w W P. - 0 I m o o N z o o a m v+ g : 3 g 1 g : IA 3 g F. x c 'DI-13 Q i 3 3 3 a s o ' 3im m r O a y s S n o y m n m m a N 9 c -. 0C-o o r [n 1 T r c w / O a S a' m m m z m E---1 Z V � - m N j 1 CD O' W o d �- � vz w a co) D 0 O F 3 O 5g ., a p > CT co T ow a A 0 c0 WM -4 a m to o rn o w N_ rn rn O N_ to m W to N CD O'CS- W n n n = n n n n n n n rf r N -1 -g au —. 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T IO _ 2 ai 0 0 0 O O O -I1 ao cbc4rSagg0000000000m m 0 1-30 C C •• m m • 1 LS. qq((�T O D 3 d Oa 01 N+ OOD OV7007 O/W NN P.O W 1 T v 3 m r s 5 5 g a g 0 0 0 0o O O O o c p 3 a5 C c �' � O m O a 1 T c 72 o o 0 ▪ 0 3, O mC a n ? 0 1 w G0 0 1 5 Z ° L7 V 07aa + 07aa v07aa v' V) • 3 a m' m' m 3 . ° g n , -, s04 .41 -. 03441-. 0, 44. ,,B11 V 07pNpNp pN (bNN ipv� mr.3pNOy a nn o v N 1 a G) rn m jON0000058000S00: Io r..0 m r O 3 a a u T.. o 3 < m ^ = r m m 11 N N NNOUNN N II D O O V O N W O c Z A ''111-i'' " Oo -• 0 8 t n -4 N df W W a a W W N N N O `i y °o " 0D o a' 4`":2 a N p m m oN V w m NOD W N W g 0 0 0 < A O A mg D +00000000000 . 00 3 0 r3O z 3 3 0 0 = y v M m z d w m m o N m m , ' a i • 1 a 8 — a 3 a 3 m O $ o A 0 A N A N A N r i r i v v m IN E 53 '. , (6' 0280 0NON0 0N (T0Wq .> HO 3 a m.i O 81g : O N a N (T N OO W m m N II IIU ." II A OI 0)O O N A O) �- O OV A ON) g 1 A A A 00A M j j MOD 0800 m N r O O f-oO MN)N O O O O O W C O C '0 w w o (T (T(71(T V V Cavil N c D m c D 0 007 w w w w z z 1 1 C 0 O 0 0 0 0 1•4I•3 0 (n CO rn r g g g 0 0 o m m m 511- Z O D •= A m m o �. (O(D N N tio w N N N t0 00 N m . ai f'�'1 E o O 00 OD O OD O W OD O OD O 0 OD O v Ip `Ip Z N d D N) { 41 (D NI 3 D O 1 :.I.' O m 0 o 2 � S 2 „' §' m i4. O p rm M N) N 0 D N) w 1 o w o m Z Z F m ' i W A_ W N _, O w V 0 N 0 w j 07 0 Z N W O N' 8 II Q C m a o a 0 a 5 S N N N O �l (mi (m0 �+ w.A A a o m 3 O mc 3 m n .3 y m m • W O) O N N CT r II II 11 II II II II II IC If II z C O O Z 8 A m — A ( mNIm 00 r W-IWOUNWw o NA --ImWm3 O'4 m c A A O co m n C (O (p m m NO0m 0 0 W ia O A W O Z p p p p p m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 It , < y Z a W m u W gi 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 a . 3': 2 O O O O O O O O O O O O O g m x9 m F 0p m a _0-),t' w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg 2 / DATE: Wednesday,May 13,2015 P.I.Supervisor '�f� v��If'S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IR-23 FROM: Lou Grimaldi KUPARUK RIV UNIT 1R-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-23 API Well Number 50-029-22200-00-00 Inspector Name: Lou Grimaldi Permit Number: 191-101-0 Inspection Date: 5/8/2015 Insp Num: mitLG150508121909 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-23 - Type Inj w TVD 6712 ' Tubing 2200 • 2200 2200 2200 PTD 1911010 Type Test:SPT Test psi 1678 IA 730 2900 - 2810 • 2800 - Interval 4YRTST p/, P ✓ OA 160 430 . 415 - 410• Notes: 4.1 bbl's diesel pumped,t3.6 bbl's returned.Good solid test.All required paperwork supplied prior to test. r 4 41t( t e2%' : I) at(7 .j 7-1=0 p1QSStAJ plot- Ct rretid- iJ l she , SNE© JUL 1 0 2015 Wednesday,May 13,2015 Page 1 of 1 d we j/e oq P� O O LO O Lo • 1 •. N : a-) . - . . — Q Q • :: -Ln : : : N : Q O ) .: .. 0 ca • N 1.0 _ (a O • • : r . : : : 22 LL Q : i N _ r- Y .1 I [ t. t ' 1 .r 1 t if 1 • 1 •1 `t t It 1. i • t •t .1 La) O a O o 0 0 UL~iO 0 LOU 0 0 0 0 LO N r- r- 1 1 ISd 1. • \ KUP INJ 1R-23 ConocoPhillips Well Attributes rax Angle&MD TD Alaska 11 1, Wellbore APIIUWI Field Name Wegbore3tatus l r) MD(BNB) Ad Btm(hKB) f,...,nslim 500292220000 KIIPARUK RIVER UNIT INJ 6610 3,000.00 12,180.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(h) leg Release Date 10-23 t0n/20t89 it 13 AM SSSV:TRDP Last WO: 1/611992 4299[ 1027/1991 Vencal ad,emalc(an,ur Annotation Depth(ItKM) End Date Annotation Last Mod By End Date Lest Tag SLM 11,687.0 10152014 Rev Reason.TAG lehal8 10/7/2014 I Casing De Strings �� Casing Description OD(in) ID(in) Top(KKB) Set Depth(hKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "'"^ _. _I CONDUCTOR 16 15.062 44.0 123.0 123.0 62.50 H40 WELDED MANG,_P 3£S—y }-.I I Casing Description OD(in) ID(in) Top(hKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len IL..Grade Top Thread . - SURFACE 9 5/8 8.921 42.0 6,330.8 4,072.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ItKB) Set Depth(hKB) Set DepthlfVD).•.Wt/Len(I...Grade -Top Thread PRODUCTION 7 6.276 29.2 12.177.7 7,002.5 26.00 L-80 NSCC i , 'I...Tubing Strings r- Tubing Dascuiption -String Iia...16(.n) -Top Its) Set Depth(n.Set Depth(TVD)(... Grads -Top Connection it TUBING WO 312 2.992 38.3 11,6099 6,7267 9.30 J-55 EUEABMOD I , Completion Details Nominal ID ,v,�� Top(KKB) Top(TVD)(111(0) Top Inel(1) Item Des _ Corn (In) coNDUCTOF.d/o In 0, a 38.3 38.3 0.01 HANGER FMC GEN 1V1`UBING HANGER 3.500 1,816.0 1,7194- 39.09 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 11,529.9 6,689.0 61.87'NIPPLE 'TIS X SELECTIVE LKNDING NIPPLE 2813 11,567.5 6.706.7 61.89 PBR BAKER PBR 3.000 SAF Flvvw 1e16o i 11,5812 6,713.1 61.90 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8 11,597.5 6.720.8 61.91 NIPPLE OTIS XN NIPPLE NO GO 2.750 11.609.2 6,726 3 61.88-SOS BAKER SHEAR OUT SUB 2.992 Perforations&Slots Shot Dena GAS LIFT,3.250"/ Top(TVD) (Urn(7/0) (shotsll 111 Top(fKB) BBB(11KB) (RKB) (hKB) Zone Date 6 Type Corn 11,710.0 11,770.0 6,774.1 6,803.1 C-2,C-1, 1/5/1992 10 0 (PERF 4.5-Csg Gun;60 deg ph UNIT B,1R- 23 Mandrel Inserts st all en NTop(100) Valve Latch Pod Sloe TRO Run Top(RKB) (hKB) Make Model 00(in) Soto Typo Type (n) (psi) Run Date Com -11 3,250.7 2,493.2 CAMCO 'KBUG- 1 GAS LIFT -DMY BK 0.0064 OA 10/27/T992 M 2 11,A84.5 6,667.5 OTIS LBD 1 1/2-GAS LIFT —WY HM 0.000 6l)4/1/1992 Notes:General&Safety • End Date Annotation [. 10/1912010 NOTE View Schematic WI Alaska1thernatic9.0 S.I//ACF Ai063306� FI 9/192013 NOTE PROD CSG RKB per RIG DETAIL SHEET _-4/P GAS 111 1.11 4}1 1.— NICE,r 11'T/ P60 116676 •108,6, FA<,FR 17.5813 GP,.1E tl 59, IS 11 GT;7 • 'PERF,11.718.0-11.7700— PRODUCTION.29.2.12,/77.7 A. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. o, PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: 'DIGITAL DATA [] Diskettes, No.' OVERSIZED Other, No/Type . . . . Logs-ofvarious~ kinds . · , .~' Other Complete COMMENTS: Scanned by: , Beverly Dian~Nathan Lowell , 1_ , i TO RE-SCAN Date: Notes:- Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is/ • • . . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 18, 2011 'j lie i ;,I to 2 fiti, Mr. Dan Seamount Alaska Oil and Gas Conservation Commission ��� ail 333 West 7 Avenue, Suite 100 Clog. Conn,' Anchorage, AK 99501 t {`'r n Dear Mr. Seamount Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1R-23 PTD 191 -101 surface casing starter head repair. Please call Perry Klein or MJ Loveland at 659 -7043 if you have any questions. Sincerely, 2 ° V " gp u3 , / 2 Perry Klein - - ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA OPASKA OIL AND GAS CONSERVATION C ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Fbrforations r Stimulate r Other r Starting head Alter Casing r Rill Tubing r Perforate New Pool r Waiver � Time Extension �"' weld Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 191 -101 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service j - 50- 029 - 22200 -00 "- O 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0025636 - —1R-23 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 12188 feet Plugs (measured) None true vertical 7008 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 11581 true vertical 0 feet (true vertucal) 6713 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 123 123 0 0 SURFACE 6289 12 6331 4073 0 0 PRODUCTION 12149 7 12178 7003 0 0 RECEIVED Perforation depth: Measured depth: 11710'- 11770' True Vertical Depth: 6774' - 6804' 1. i 1 \l d a ._ 01 Alaska Oil & Ciao Cans. Dm Tubing (size, grade, MD, and TVD) 3.5, J - 55, 11609 MD, 6726 TVD .00Oqfilge Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB RETRIEVABLE PACKER @TI:1 and 6713 TVD SAFETY VLV - CAMCO TRDP -1A SAFETY VALVE @ 1816 MD and 1719 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 1 2. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service ` Fro Stratigraphic r X 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations GSTOR r VVINJ r WAG F GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt NA Contact MJ Loveland /P Printed Nam- 'er lein Title Well Integrity Project Supervisor A Signature Phone: 659 -7043 Date // // li t Vfd _ fil3DMS JUN - 211011 $& &2t -(( Form 10-404 Revised 10/2010 Submit Original Only • 1R-23 0 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/03/11 SET 2.81" XXN PLUG @ 11, 598' RKB, PERFORM PASSING 2500 PSI MIT ON TBG, BLEED DOWN T /I /O = SI/0/0. READY FOR WI. 06/09/11 Pre heat and weld thread leak between casing head and casing mandrel hanger (Braden head). 06/10/11 MIT -OA ( passed ), T /I /0= SI/0/0. OA -FL NS. Pressured up OA with 4.56 bbl diesel, T /I /O= SI/0/1800. 15 min T /I /O= SI/0/1720. 30 min T /I /O= SI/0/1690. Bled OA, T /I /O= SI/0/200. _ __ ill ar . I :x b�"L � 3 ■ l iP l' ) t y u��M ii t ..t ,,. .,. i . ,. . , ,. , . . , , .. • Al - 3,,,, ..* sr t ..... . I\ , ...Iv . - ..'-i - )044 ' M.' . ' a omansworc Y ... '. R we . pine' ' l ,. � .►.. - .. . s w - r . r. .. .. . rr.. i. '. 1:,✓ W" a . � te, 4.A.-- q i r ..° ........ oir.... _ .'?Y+r /*1itw�.�.t s.41.....? it 4 ii ' . 641"' 2'4'. JP Or- jpp. i ppi r ,e Opp- ' ' • . -4 111111111111104=4 ., . f igh lit , ' . /1"11""* 1. 11111. - .). /41421/r- ." . "" 1411r- , 1 fiiiik .444000.1.74•1010.0‘ OC: • °' •Phillips Alaska.., Inc This photo is copyright by ConocoPhillips Alaska, Inc. hi and cannot be released or liamiriv r , r 1 1P r published without express ir written consent of ConocoPhillips Alaska .1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 25, 2011 TO: Jim Regg u � � z ,/ a P.I. Supervisor y q SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC 1R-23 FROM: Chuck Scheve KUPARUK RIV UNIT IR -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 1:6(2.— NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R -23 API Well Number: 5 0- 029 - 22200 -00 -00 Inspector Name: Chuck Scheve lnsp Num: mitCS110522090929 Permit Number: 191 -101 -0 Inspection Date: 5/21/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j 1R-23 ' Type Inj. N TVD 6712 ' IA 430 2175 i 2125 2115 P.T.D 1911010 • TypeTest SPT Test psi j 1678 - OA o 0 0 0 Interval 4YRTST p/F P Tubing 1025 1025 1025 1025 Notes: 5 LA SOMA`' 2 4i 20 Wednesday, May 25, 2011 Page 1 of 1 ~ C011 ~ . . ocoPhiltips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 i~~`~ ` ~~i ; f ~~ „~ ~. .. . _ . Dear Mr. Maunder: ~`. ~0~ G ~~3 ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~` and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~' and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ ~~ MJ Loveland ~ SEP 0 2 2009 Al~~k~ ~~f ~ ~~s G~ns,.Go '~sion ~t~Ch01+ ConocoPhillips Well Integrity Projects Supervisor . , i ='.-. : 1 .. ~~ ~ ~ ~ ~ ~ : ~~`t' r3- ~ ~C~9 ~ ~ `~_ .~, > _.. . ~ e ;R ~~r _. - ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 1 R PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8l15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28l2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1 R-08 50029213330000 1850730 8' 1.00 21" SN 5/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8l28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8l15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" S/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 S/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '01· . I ¡¿if {14/ è 7 DATE: Friday, May 11,2007 SUBJECT: Mechanical Integnty Tests COi\OCOPHILLIPS ALASKA rNC IR-23 KlJPARUK RIV UNIT 1R-23 \q\/~O' FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV LJNIT lR-23 Insp Num: mitRCN070510213139 Rei Insp N urn: API Well Number: 50-029-22200-00-00 Permit Number: 191-101-0 Inspector Name: Bob Noble Inspection Date: 5/9/2007 I IA OA 1030 2650 15 Min. 30 Min. 45 Min. 60 Min. I 2580 ¡ 2560 I ! +~---,--+~ -- 500 I 500 I Packer Depth Well! 1R~23 iType Inj. i w i TVD;__~__ P.T.Di 1911010 !TypeTest I SPT i Test psi ¡ 1678.25 -~-~. Interval 4YRTST P/F P /' Notes: Pretest Initial __..________L._ I -~-- 360 500 ~--~ Tubing 2100 .J. 2100 I 2100 2100 5tANNED JUN 0 6 2007 . . > ~,,~'!.............!_....,_....!'.·_Å.._ Friday, May 11,2007 Page 1 of 1 MEMORANDUM: .. TO: Dan seamount ~//~ Commissioner THRU: BlairWondzell ~ ~ P.I. Supervisor £~.~1o~ FROM: JohnCris~p· I.{'~ ~,,_ Petroleum Inspector state of Alaska Alaska Oil and Gas Conservation Commission DATE: September 28, 2000 SUBJEC.T: Mechanical Integrity Tests Phillips Alaska Inc. 1 R Pad 17,18,198,23,26 Kuparuk River Unit -Kuparuk River Field NON- CONFIDENTIAL . Packer Depth · · Pretest Initial 15 Min. 30 Min. we,,I 1R-17' IType,nj.) G )T.V.D. I ,oo I I ~oo Ilntervall' 4 P~T.D.I 1911140 ITypetestI 'P ITestpsi) 1616 I CaSingl 1500 I 2500 I 2275 I 2200 J' P/F'I _.P Notes: Pre~sure stabilized (~ 2200 hsi. Monitored for. one hour... · ' _ Welll 1R-18 I.Type Inj. I N /T'V'D' I 31'82 I'Tubing I 250 I' 250 I 250 I 250 I lntervall' 4 P.T.D.I 1910870 ITypetestl P ITestpsil''' 796--. I Casingl 900 ! .1640 I 1600 ! 1590 I P/F I P Notes': 'WellI 1R-198 J Typelnj.I S J T.V.D. I 6548 I Tubing. I 2425 I 2450 I 2~,50 I 2450 l lnter6,11 4. P.T.D.I 1910850 ITypetestI P /Testpsil 1,637-['casingI. 1~10 ! 1940 I 1.9.20 I 1920 I P/F I E Notes: Welll :. 1R-23 IType Inj. i S- "! T.V.D. I 6713' I Tubing ! 2500 J 2500 I 2500 I 2500 Ilntervall 4 ' P.T.D.I 19110*lO'lT~petestl P JmestpsiI 1678 i~:asingl ~0~ j ~00'1 ~78 I ~ss0 I P/F I __"' Notes: Well! 1R-26' I Typeln).l S "1 T.V.D. l; 6535 I Tubing I 2300 I 2300 I'''2300 J 2300 J,nterva,I 4 . P.T.D.I 1910920 ITypetestI 'P ITestpsil 1634 I Casingl 1220 .] 1720.'1. 171o1169oI P/F I__P- Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test. R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year.Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I witnessed MIT's in the Kuparuk River Field on IR Pad. The pressure on 1R-17 stabilized ~ 2200 test pressure, test was held for one hour. No failures witnessed. .I.T.'s performed: 5_ Attachments: none Number of Failures: 0 Total Time during tests: 2.5 hrs. cc: MIT. report form 5/12/00 L.G. MIT KRU 1Rb 9-28-00jc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 P M C:LORI'uMFILM.DOC L A T E E E W TE R IA L UNDER H IS M A R K ER PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 12/17/93 91-101 CBT L 91-101 CDN L 91-101 CDR L 91-101 CET L 91-101 DSSI L 91-101 ELAN GEOCHEM ANA L 91-101 USIT(C&C) L 91-101 407 R 91-101 DAILY WELL OP R 91-101 SURVEY R 91-101 5125 T SCALE DATE_RECVD R1,7994-12082 5 R1-3,6330-12188 2/5 R1-3,6330-12188 2/5 R1,7994-12082 5 R1,11580-12070 5 R1,11650-11950 5 R1,100-6320 5 COMP DATE:01/06/92 10/14/91-01/07/92 SS DIRECTIONAL OH-CDR/CDN,6200-12188 11/12/1991 11/04/1991 11/04/1991 11/12/1991 02/04/1992 02/25/1992 11/04/1991 02/27/1992 02/27/1992 01/06/1992 11/27/1991 Are dry ditch samples required? yes And ~ yes no Was the well cored? yes ~Ananlysis & d~e~7~.~J~~l-ec-e-i-~-d~. ....... yes Are well tests require~~es O~ no Well is in compliance - ~ ~ Comments ilo 1. Operations Performed: 2. Name of Operator ( '~ STATE OF ALASKA ~ ALA~ OIL AND GAS CONSERVATION COMMI~'51ON ' ~ REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging PerforateKB ~1~/~'~4 1 Pull tubing ~ Alter casing Repair well Other ~( 5. Type of Well' 6. Datum elevation (DF or ) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 426' FSL, 144' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 659' FSL, 1732' FWL, Sec. 9, T12N, R10E, UM At effective depth 962' FSL, 2030' FWL, Sec. 9, T12N, R10E, UM At total depth 1019' FSL, 2086' FWL, Sec. 9, T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 1 21 80 feet true vertical 7004 feet RKB 88 7. Unit or Property name Kuparuk River Unit Effective depth: measured 1 2088 feet true vertical 6959 feet 8. Well number 1R-23 9. Permit number/app_royal number · 91-101 I10. APl number so-029-22200 I11. Field/Pool Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 123' 16" 6283' 9 5/8" 6224' 7" 5923' 7" measured 1 1 71 0'-1 1770' true vertical 6774'-6803' Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 331 SX AS I 1 2 3' 1 23' 1170 SX PF E & 6329' 4056' 530 SX Class G 250 SX Class G 6253' 4001 ' 250 SX Class G 12176' 7004' feet Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 11610' Packers and SSSV (type and measured depth) PKR's: Baker HB @ 11581'; SSSV: CAMCO TRDP-1A @ 1816' 13. Stimulation or cement squeeze summary Convert well from oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Re_oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 300 150 60 1300 -0- -0- 1200 500 Tubing Pressure 185 2200 15. Attachments Well Schematic 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service WAG In!ector Si~lned {~' ~''). ~ Fnrrn 1 ~3-zt~34 R~.v ~.q/12/.cJcl Title RI IRMIT IN 1311Pl I~,ATI= 8t6 '8 I I99~8~z_6~"~ ' = = 0 'SqVIOI 0 0000 000'0 668~ 908G 0 o oooo ooo'o o b o oooo ooo'o ~ ~c8c o o oooo ooo'o ~o~ ~8~ o o oooo ooo'o ~,~ ~s~ o o oooo ~'? o o o o oooo ~'~ o o o o oooo ooo'o ~@ ~6, o o oooo ooo'o ~,o~ oo8 o o oooo ooo'o ~s?c ~ o o oooo ooo'o ~6~c 6~ o 0 0000 000'0 68~ ~06~ 0 00.'3 O~Z 2Z '::'.~ l ~ O0 T O01S OG~ OR~' :VEOF. O0 ~ 00I *O0'~E 00I *00~i 0.'£ ~;c~lU 00i MS 8 £~ ~:?Ic~ Og MS 8 ~l 168C 00I I0 80I zLgi~ ~0~ MS 8 & I£iU 60~ MS 8 8 z~t,]E OC MS 8 ~ -,.,~ O'b MS 8 ~3~ O~ MS 8 C BgOD N S I ~ W H VIVG IS ~DSWW OdM8 S]88 ONIGVB~ MOA Hlg~ MOA ~B£BW PNI PNI SBWAqOA NOIIDBPNI ....... : ,, ± B "l .m'-' '-, '- ,-=,., P'N ~ V N -1 ,,Z. B~'>~OI-I 3 I 0 S Z M SAIVIS - '~'"' ' 'S]~lOi 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 )O N S I ~ W H G'9 9Z& 9tZ 0 8'I 000I 9Z8 0 £'9 O00E &80E 0 C'E 8Z9 818 0 ~'~ Z~@ ~ 0 ~'0~ OOG~ ~ 0 0'0~ 00~ ~ 0 ~'I IZ~ ~0~ 0 ~'~ 00~ GO£ 0 9'~ 99EI ~I 0 b'O Og 6II 0 00~ OOEI OG 09E OGll 6~ 00~ OE8 O~ OgI O00l O~ OOE O~ET 09 OOC OOET 09 OOg O~8T O~ *OgOI OBiT 09 0 08ET 0'~ 009 O0~l G~ 0 006 O~ OOZ 009 OOC ~d 8 &E ~d 3 ZE ~d ~ TE ~d 80~ ~d 8 ~I ~d V TI SIO0~ O~DSW ~DSW ONIOVB~ ISa ]0 31V~. qOa ~alBW ldO ldO PNI ,,01 SVO SVO S± 8 I J. B -1 V N 'l E¥iOHD J.. 0 q S Z M .VO IS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 DECEMBER 29, 1992 WATTY STRICKLAND ARCO ALASKA INc. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 91-0114 KUPARUK RIVER UNIT 1R-17 91-0085 . KUPARUK RIVER UNIT 1R-19RD 91-0092 KUPARUKRIVER UNIT 1R-26 91-0101 KUPARUK RIVER UNIT 1R-23 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION DECEMBER 28, 1992 IN A CONVERSATION I HAD WITH VICTORIA FURGENSON. THESE WELLS HAD 403 SUNDRYS SUBMITTED EARLIER IN 1992 TO CONVERT THESE OIL WELLS TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS WERE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S WHEN THE CONVERSION WAS COMPLETED. THIS MATTER NEEDS TO BE CORRECTED SO OUR FILE ARE CURRENT AND UP TO DATE. WOULD YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALI' SR PETR GEOLOGIST i'~"~ . STATE OFALASKA ALA~ OIL AND ~ CONSERVATION COMMI,.,,.,,ON APPLICATI. ON 1, Type of Request: Abandon _ " SUsPend Alter casing _ Repair well _ Change approved program X 2, Name of Operator ~ 5. Type of Well: ! Development ARCO Alaska. Inc. Exploratory 3, Address ~ Stratigraphic P. O. Box 100360, Anchorage, AK.. 99510I . $,ervice 4, Location of well at surface 426' FSL, 144' FWL, SEC 17, T12N, R10E, UM At top of productive interval 659' FSL, 1732' FWL, SEC 9, T12N, R10E, UM At effective depth 962' FSL, 2030' FWL, SEC 9, T12N, R10E, UM At total depth 1019' FSL, 2086' FWL, SEC 9, T1. 2.N,. R10E, UM 12, Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Length FOR SUNDRY APPROVALS oPeration Shutdown _ Re-enter suspended well_ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 1 21 80' feet Plugs (measured) 7004' feet 1 2088' feet Junk (measured) 6 9 5 9' feet Size Cemented 1 2 3' 1 6" 331 Sx AS I 6331' 9-5/8" 1170 Sx PF E & 530 Sx Class G 1 21 78' 7" 250 Sx Class G Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ORIGINAL RKB 88'. PAD 45' GL feet 7, Unit or Property name Kuparuk River Unit 8, Well number 1R-23 9, Permit number 91-101 10, APl number 50-029-22200 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None Measured depth True vertical depth 123' 123' 6345' 4056' 7004' ! R L I iVED S E P 1 § 1992 measured ! 1 710'-11 770' true vertical 6774'-6803' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 11610' Packers and SSSV (type and measured depth) Alaska Oil & Gas Cons. 60mmissi0n Anchorage Camco TRDP-4A SSSV @ 816, Baker HB Retr. Pkr @ 9569' & Baker 35-32 D Perm. Pkr @ 9706' 13, Attachments Description summary of proposal X~ Detailed operation program _ BOP sketch _ Convert well from oil producer to WAG.i.nj~c.tori...(Wel!bore schematic attached). 14, Estimated date for commencing operation !5. Status of well classification as: October, lC~Cj2 Oil __ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service .WAG In!ector 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Sicjned C, ~), .~ Title Eng,ineer ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance Mechanical Integrity Test~, Subsequent form require Original Signed By David W. Johnston Date ~//I/c~Z- Approved by order of the Commission Form 10-403 Rev 09/12/90 JApproval No, 1 O- ,'~ ~'~':,.,-~,~': ::.:~ Gog¥ Commissioner Date SUCMIT I~ ~RIPLICATE Well 1R-23 Conversion to WAG Injection ARCO Alaska requests approval to convert Well 1R-23 from an oil producer to a WAG injector. This well will be operated as a Class II UIC well in compliance with. Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 11,710' MDRKB and 11,770' MDRKB This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED $ E P 1 5 1992 Alaska Oil & Gas Cons. (;ommissio[~ Anchorage W~ll:l R-2:) Spud Date: 9-28-91 Completion Date' 1-6-92 AR~~ ALASKA INC. - KUPARUK ~LD APl# 50-029-22200-00 Well Type: WATER INJECTION C Sand: CPE~ Tree Type: FMC GEN IV 5000# A Sand: N/A Tree Cap Type: OTIS Maximum HoleAngle: 56.1 deg. @ 3000' MD Original Rig RKB: 38' All depths are MD-RKB to top of equipment. Tree Cap Size: Tree Cap O-ring ASN' Last Workover Date: 1 - 6 - 9 2 Z~~ LL Jewelry 1 SSSV: CAMCO TRDP-1A 2.812" ID @ 1816' 2 SLN: OTIS 'X' 2.813" PB ID @ 11530' 1 3 PBR: BAKER 3.0" ID @ 11568' 4 PKR: BAKER 'HB' RETR. 2.89" ID @ 11581' 5 NOGO: OTIS 'XN' NIPPLE 2.75" ID @ 11598' 6 SHEAR OUT: BAKER @ 11609' 7 TUBING TAIL: 3 1/2" TUBING @ 11610' Minimum ID:2.75" NOGO J Casing and Tubing Pipe Tally Size Wei{3ht Grade Tot~ Bottom ~ 1 6" 62.5# H-40 0 123' CASING 9 5/8.. 36# J-55 0 6331' CASING 7" 26# L-80 0 6214' CASING 7" 26# J-55 0 12177' UNER 3 1/2" 9.3# J-55 0 11610' TUBING J Gas Lift Information Depth Stn# Valve Tvoe Sz. Latch port _ _ 3251' 1 KBUG-M D/V 1" BK2 11484' 2 LB CI-K 1.5" RM 3 ¢ 2 3 x x , RECEIVED S E P 1 § 199 ? 5 Alaska 0il & Gas Cons. Commission 6,7 ~h0rage -' Perforation Data Interval SPF Date Zone Comments 11710-11770 10 1/5/92 C Sz. AID# Date Run 1-6-92 1 -6-92 Comments: LASTTAG: 11910' ON 1 -26'92 TD: 12180' PBTD: 12088' LAST REV: 3-2-92 meb ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-03 - LIS Tape and Listing I -27-92 92095 3 R- 12 D LIS Tape and Listing 2 - 4 - 9 2 92115 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK. YOU. Y'/'"-//~ I R-17 ~/--/,~' 1R-20 ?/_//~ 1R-21 ~/_~.o?' 1R-22 ~/_/ot 1R-23 ,~/..-~$ 1R-24 ~,/.-.~ I R-26 ~/-../,~- I R-27 f~/- ?~ 1R-29 · ~ / .--,~/ 1R-19 ?/./~/ 2M-21 ~/--/-~' 2 ~ -2139 f,/--~'~ 1 - f'/~'~' 1 L-24 f¥_?o 1 L-25 f'/-'~f I L-26 Receipt LIS Tape and Listing 9 - 1 9 - 91 92026 LIS Tape and Listing 9 - 9 - 91 92026 LIS Tape and Listing I 0 - 6 - 91 92026 LIS Tape and Listing 9 - 24 - 91 92026 LIS Tape and Listing 1 0 - 22 - 91 92026 LIS Tape and Listing 7 - 3 0 - 91 92026 LIS Tape and Listing 7 - 1 8 - 91 92026 LIS Tape and Listing 8 - 31 - 91 92026 LIS Tape and Listing 8 - 1 4 - 91 ' ~' 92026 LIS Tape and Listing 6 - 1 9 - 91 92026 LIS Tape and Listing 11 - 1 I - 91 92026 LIS Tape and Listing 1 I - 1 7 - 91 92026 LIS Tape and Listing 5 - 9 - 91 92026 LIS Tape and Listing 5 - 1 9 - 91 92026 LIS Tape and Listing 5 - 26 - 91 92026 LIS Tape and Listing 6 - 3 - 91 92026 Acknowledged: R-EC--E VED DISTRIBUTION: Lynn Goettinger FEB 2 8 1992 Alaska 0il & Gas Cons. Commission Anchorage State of Alaska 0 R I G I ~' ' ,(~ STATE OF ALASKA ? ' ALAoKA OIL AND GAS CONSERVATION COMMISSION _.~ 4~., WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL r~ GAS r--] SUSPENDED r'~ ABANDONED [~] SERVICE 2 Name of Operator 7 Pen~# Number ARCO Alaska, Inc 91-101 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360,,,, __ 50-029-22200 4 Location of we, atsurface J C~,~i~ ,"~"'-=-'"'~'~". 9 Un. or Lease Name 426, FSL, 144, FWL, SEC17, T12N,RlOE, UMi~~.' -- -"""u'~'I 659' FSL, 1732' FWL, SEC 9, I~ -~'/~,,~-- [ · 1R-23 T12N, R10E, U ~ At Total Depth'[=~~----------~----=~ .~ ..... 11 Field and Pool 1019' FSL, 2086' FWL, SEC 9, T12N, R10E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Dasignalion and SePal No. KUPARUK RIVER OIL POOL RKB 88', PAD 45' GLI ADL 25627, ALK 2560 12 Dale Spudded 13 Date T.D. Reached 14 Dale Comp., Susp. or Aband. 115 Water Depth, i~ offshore 116 No. of Completions 10/13/91. 10/21/91. 01/06/92.I NA feet MSLI 1 17 Total Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey i26 De~h where SSSV set 21 Thickness of pen~afrost 12,180' MD, 7004' TVD 12,088' MD, 6959' TVD YES ~'] NO--L_J 1816' feet MD 1700' APPROX 22 Type Electric or Other Logs Run CDN/CDR/GR/CET/CBT/G YRO 23 CASING, UNER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER Fi'. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 123' 24" 331 SX ASI 9-5/8" 364~ J-55 SURF 6331' 12-1/4' 1300 SX PF E, 630 SX CLASS G 7" 26fl J-55 SURF 12,178' 8-1/2" 380 SX CLASS G 24 Perloralions open to Production (MD+TVD of Top and Boltom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET (MD) 3-1/2",9.3# 11,610' 11,581' 11,710' -11,770' W/4-1/2' CSG GUN ¢~ 10 SPF MD 6774'-6803' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMeth°d of Operalio~ (Flowing, gas lilt, etc.) I Date of Test Hours Tasted PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (con') Press. 24-HOUR RATE · 28 CORE DATA Brief dascription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.K E F .9 2 7 1992 Alaska 0il & Gas Cons. ~ummissi0n Anchorage / Submit in duplicate / Form 10-407 Rev. 7-1-80 _ C,~-CI. OGIC ~ FORMATiCN TESTS ,, NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, lV~.AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 11601' 6722' NA KUPARUK C Bo'FrOM 11770' 6803' KUPARUK A TOP 12035' 6933' KUPARUK A BO'I'TOM Below TI3 Below TD 3i. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .... ~'~ .~_~ Title AREA DRLLI~iG ENGI~IE'I~R 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". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 1R-23 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25627 ALK 2560 50-029-22200 91-101 ACCEPT: 10/13/91 SPUD: 10/13/91 RELEASE: 10/25/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK6403 10/14/91 (1) TD: 1260' (1260) SUPV:JR 10/15/91 (2) TD: 4130' (2870) SUPV:JR 10/16/91 (3) TD: 6345' (2215) SUPV:JR 10/17/91 (4) TD: 6345'( SUPV:KKL o) 10/18/91 (5) TD: 6455' ( 110) SUPV:KKL 10/19/91 ( 6) TD: 8380' (1925) SUPV:KKL 10/20/91 ( 7) TD:10395' (2015) SUPV:KKL DRILLING 12-1/4" HOLE MW: 9.0 VIS: 54 · MOVE RIG FROM 1R-21 TO 1R-23. NU DIVERTER AND PT. DRILL FROM 123-1260. DAILY:S79,995 CUM:$79,995 ETD:S79,995 EFC:$1,910,000 DRILLING 12-1/4" HOLE MW: 9.0 VIS: 46 DRILL FROM 1260' - 3114'. REPAIR ELECTRICAL SYSTEM ON TOP DRIVE. DRILL FROM 3114'-3579. CBU AND POOH FOR BIT CHANGE. RIH AND DRILL FROM 3579'- 4130'. DAILY:S69,194 CUM:$149,189 ETD:S149,189 EFC:$1,910,000 SHORT TRIP 9-5/8"@ 6330' MW: 9.4 VIS: 42 DRILL FROM 4130' TO 6345'. PUMP HIGH VIS SWEEP AND CBU. SHORT TRIP AND CONDITION HOLE FOR RUNNING SURF CASING. DAILY:S58,147 CUM:$207,336 ETD:S207,336 EFC:$1,910,000 NU BOP 9-5/8"@ 6330' MW: 9.3 VIS: 40 CIRCULATE AND CONDITION MUD FOR 9-5/8" CSG. RUN 9-5/8" CSG TO 6331'. CMT 9-5/8" CSG WITH HOWCO PERM. E AND CLASS G CMT. BUMPED PLUG, FLOATS HELD. GOT APPROX. 145 BBLS OF CEMENT BACK TO SURFACE. ND DIVERTER AND NU BOPE. DAILY:S207,931 CUM:$415,267 ETD:S415,267 EFC:$1,910,000 DRILLING @ 6455 9-5/8"@ 6330' MW: 8.9 VIS: 35 NU AND TEST BOPE. PU BHA AND RIH TO TOP OF CEMENT AT 6237' TEST CASING TO 2000 PSI - OK. DRILL FC, FS, AND 10' OF NEW HOLE. TEST FORMATION TO EMW OF 12.3 PPG - OK. RESUME DRILLING 8.5" HOLE. LOST 600 PSI. POOH AND FOUND WASHOUT AFTER PULLING 41 STNDS. RIH AND CONTINUE DRILLING FROM 6355' - 6455'. DAILY:S82,040 CUM:$497,307 ETD:S497,307 EFC:$1,910,000 DRILLING AT 8380' 9-5/8"@.6330' MW: 9.2 VIS: 38 DRILL FROM 6455' TO 6756'. POH FOR MWD FAILURE. RIH AND CONTINUE DRILLING FROM 6756'-8380' DAILY:S51,159 CUM:$548,466 ETD:S548,466 EFC:$1,910,000 DRILLING AT 10395' 9-5/8"@ 6330' MW: 9.2 VIS: 36 DRILL FROM 8380' TO 9950'. WORK ON ANADRILL'S SURFACE MWD EQUIPMENT. DRILL FROM 9950' - 10287. POH LOOKING FOR WASHOUT. WASHOUT FOUND IN STDN #73. RIH AND DRILL FROM 10287' - 10395'. DAILY:S53,726 CUM:$602,192 ETD:S602,192 EFC:$1,910,000 WELL: 1R-23 OPERATION: DRILLING RIG: POOL 7 10/21/91 (8) TD:11749' (1354) SUPV:KKL 10/22/91 ( 9) TD:12180' ( 431) SUPV:KKL 10/23/91 (10) TD:12180' ( SUPV: KKL o) 10/24/91 (11) TD:12180' ( SUPV:DS o) 10/25/91 (12) TD:12180' ( SUPV:DS o) 10/26/91 (13) TD:12180' ( SUPV:DS o) PAGE: 2 POH FOR BIT CHANGE 9-5/8"@ 6330' MW:10.6 VIS: 38 DRILL FROM 10395' TO 11749'. CBU. POH TO 6759' TIGHT HOLE AT 11420', 11325', AND 10951. RE-LOGGING F~OM 6759' TO 9-5/8" SHOE. DAILY:S95,585 CUM:$697,777 ETD:S697,777~ EFC:$1,910,000 CIRC FOR SHORT TRIP 9-5/8"@ 6330' MW:10.7 VIS: 41 LWD PASS WHILE POH FROM 6759' TO 6330' (SHOE). CONT POH, C/O BIT. RIM WITH NEW PDC BIT AND TURBINE. REAM FROM 11 200' TO 11,749'. DRILL FROM 11,749' TO 12,180' CIRC AND COND MUD FOR SHORT TRIP. DAILY:S78,668 CUM:$776,445 ETD:S776,445 EFC:$1,910,000 RIH TO COND FOR CSG 9-5/8"@ 6330' MW:10.7 VIS: 42 CIRC AND COND FOR SHORT TRIP. SHORT TRIP TO 10417' LOG , WITH LWD FROM 11,732' TO 11,980' AT 120 FT/HR. POH, DOWNLOAD LWD DATA. RU SWS WIRELINE UNIT. RUN USIT CASING INSPECTION LOG FROM 9-5/8" SHOE TO SURFACE. RD SWS, PU BIT AND RIH TO CONDITION FOR RUNNING 7" CASING. DAILY:S141,894 CUM:$918,339 ETD:S918,339 EFC:$1,910,000 RUNNING 7" CASING 9-5/8"@ 6330' MW:10.7 VIS: 44 CONTINUE RIH TO 12180' FOR WIPER TRIP. CIRCULATE AND CONDITION MUD. POOH. BEGIN RUNNING 7" CASING. DAILY:S74,718 CUM:$993,057 ETD:S993,057 EFC:$1,910,000 NU FMC CSG HEAD/TREE 7"@12177' MW:10.6 VIS: 38 CONTINUE RIH WITH 7" CSG. CEMENT 7" WITH 83 BBLS OF CLASS G. BUMP PLUG TO 3500 PSI. TEST CASING FOR 15 MIN.-OK. LAY DOWN 5" DP. ND BOPE, NU TREE. DAILY:S340,432 CUM:$1,333,489 ETD:S1,333,489 EFC:$1,910,000 RIG RELEASED 7"@12177' MW:10.6 VIS: 0 CONTINUE NU FMC WELLHEAD. INJECT DIESEL TO FREEZE PROTECT 7" X 9-5/8" ANNULUS. TEST PACKOFF TO 3000 - FAILED. HOOK UP VAC TRUCK TO LOWER VALVE AND APPLY VACCUM TO 7" X 9-5/8" ANNULUS TO SEAT PACKOFF. RETEST PACKOFF TO 3000 PSI - OK. RELEASE RIG. DAILY:S22,633 CUM:$1,356,122 ETD:S1,356,122 EFC:$1,910,000 DRILLING SUPERINTENDENT ARCO ALASKA INC. WELL: 1R-23 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT F IELD: KUPARUK RIVER FIELD LEASE: ADL 25627 ALK 2560 API: 50-029-22200 PERMIT 91-101 APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/05/92 SPUD: RELEASE: 01/06/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK6403 01/06/92 (14) TD:12180 PB:12088 SUPV:DB/LH RUN 3-1/2" COMPLETION 7"@12177' MW:10.6 NaC1/Br ACCEPT RIG AT 06:00 HRS,SET TEST PLUG, NU BOPE,TEST SAME TO 3000 PSI,RU SWS, TEST LUBRICATOR TO 1500 PSI,PERFORATE 'C' SAND W/4-1/2" CSG GUNS,5 SPF, 60 DEG ORIENT +/- 150 DEG CORRELATE DEPTHS TO CBT DATED 10-21-91,GUNS #1,2:11750- 11770,GUNS #3,4: 11730-11750, GUNS# 5,6: l1710-11730,POH, RU TO RUN COMP,RUN 3-1/2" SINGLE COMPLETION AS PER PROCEDURE DAILY:S72,243 CUM:$1,428,365 ETD:SO EFC:$3,338,365 01/07/92 (15) TD:12180 PB:12088 SUPV:DB/LH RIG RELEASED 7"@12177' MW:10.6 NaCl/Br FINISH RUNNING 3-1/2" SINGLE COMPLETION AS PER PROCEDURE,MU SSSV AND C-LINE, TEST SAME TO 5000 PSI,OK, CONT RIH W/COMP,MU TBG HGR AND C-LINE, TEST SAME TO 5000 PSI,OK, LAND HGR, RILDS PRESSURE TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI,HOLD PRESSURES FOR 10 MIN, BLEED ANNULUS,HOLD 1800 PSI ON TBG, BOLDS PU AND SHEAR PBR AT ll6K#,BLEED OFF TBG, RELAND HGR RILDS,TEST SSSV W/500 PSI DIFF. F/15 MIN, OK, TEST ANNULUS AND TBG TO 2500 PSI F/15 MIN, OK, PRESS UP TBG TO 3150 PSI AND SHEAR SOS,BLEED OFF PRESS,CLOSE SSSV, LAY DN LANDING JT, SET BPV, ND BOPE,NU TREE, TEST TREE AND PACKOFF TO 5000 PSI,OK DISPLACE ANNULUS WITH 12 BBL DIESEL, BULLHEAD TBG W/4 BBLS DIESEL, SECURE WELL, RELEASE RIG AT 20:00 HRS 06-JAN-92 SITP=800 PSI FALLING, SICP=200,SIAP=0 DAILY:S169,152 CUM:$1,597,517 ETD:SO EFC:$3,507,517 FEB 2 7 1992 Alaska 0il & Gas Oo~s. t, ut~lmission Anchorage DRILLING SUPERINTENDENT II ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE r~l ONTINUOUS F~ OOL Company ARCO ALASKA, INC Well Name 1R-23(426'FSL,144'FEL,SEC 17,T12N,R10E) Field/Location KUPARUK, NORTH SLOPE, ALASKA · Job Reference No. 75325 Locjcjed BV: K. BARNARD FEB 2 7 1992 Alaska Oil & (:las Cons. Anchorage Date 29-0CT-91 Computed By: R. KRUWELL I SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1R - 23 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 29-0CT-91 ENGINEER: K.BARNARD METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. 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NOII3]PO~Id '!¥311~3A (30I~'NZII'ZI 33S'13J,~I'lSJ,9~) £Z-BI : 993~ ^OGCC GEOLOGICAL M^TEH!^LS INYENTOHY LIST i IIII , III I _ _1 I I IJll I I IIII ,1'1111 I,III IL I,'1, III I I !' f~rm received received date comment9 - -~03-'- yes no sUndry, application ' ~04 yes .... no .......... r~port ofsund~ application Open required received Cased required received Productio[ required received .,, ,h,~le !og .... hole Io~] , . .log ~ "'- -'~ TEMP MUD GCT ..._~. DIL/SFL CNL .... ~' PROD i, .... · BLL CBT ~ ~' PRESS BHClSL C~T ~ ~PIHHEFi ............................................................BHC/AC EFrr .................. 'SSS ....................... PACKER ' Digital. FDc.' '" ~' ' / Well L_ CNL L)~ I1~' q~ Te~l~ FDC RWD rc ' ,;-- [cccivcd~ ~AMPLES'itcquired received :LDT/'CNL ........... CYBER LOOK ..... RF[ .... ARCO Alaska, Inc. Date' February 21, 1992 Transmittal #: 8365 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 2---~ L,,¢ 3 R- 1 2 3R 12 ~/--y~( I R-23 Cement Evaluation Log Cement Bond Log ELAN Geochemical Analysis 2-6-92 50-3575 2-6-92 50-3555 I 2-25-91 1 1 650-11950 Receipt. Drilling Acknowledge' State ::of Alaska(+sep~a) Date' NSK RF( 'EIvED FEB 2 5 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return o. ne signed copy of this transmittal. 2M-10 Litho-Density & Casing Neutron 11-29-91 7000-7756~~ Porosity Data & 12-29-91 7000- 7669 2M-1 0 Litho-Density & Casing Neutron I 1 -29-91 7000-7756 I f g: Raw Data CCN ~ 1-12-16-92 CDR ~ 1-12-16-92 CCN t~ 1-24-27-92 CDR ~ 1-24-27-92 & 12-29-91 7000-7669 4517.7-7720 4517.7-7720 5090-9640 5090-9640 .~THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUESTED ~ THAT YOU TH;ROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG..,,,.~ /\ _THANK y~U: ~'., - .. - '5-9-13-91 6-3-6-91 11-17-'91 11-il-91 9-15-19-91 6-19-23-91 9-9-91 10-6-11-91 9--24-29-91 10-22-91 7-30/8-5-91 7-18-21-91 8-31 -91 8-14-91 5-19-22-91 5-26-29-91 5237-1 0476 '-~ 5.225-1 0065 3835-9250 3914-10599 5698-10345 5390-9841 5568-10080 5070-10180 6001-10813 6330-12188 6753-12972 5591-10218 6547-9250 6042-11368 5081-9241 / 4978-9352 RECEIVED FEB 1 '~ 199?- Alaska Oil & Gas ConS. Cemmission Anchorage ARCO Alaska, Inc. Date: January 31, 1992 Transmittal #: 8351 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 R-23 Receipt Dipole Sonic Imager 1 2-29-91 1 1580-12070 Acknowledged: --~---~ .... Date: .......... DISTRIBUTION: D&M Drilling NSK Vendor Package(Johnston) I EC'EIVED FEB 0 4 1992 0tl & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 3, 1992 Transmittal #: 8321 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box. 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. ~1 I'"1°1 1R-23 / Please acknowledge receipt and return Sub-Surface Directional 1 2 - 3 - 9 1 75326 Survey Sub-Surface Directional 1 0- 2 9 - 91 75325 Survey ReceiPt Acknowledged: D&M .................. Date: Stat~.of~Ai~Ska .~.. RECEIVED JAN ~0.6 1992 Alaska 011 & Cas Cons. C0mmission Anchorage ARCO Alaska, Inc. Date: November 22, 1991 Transmittal #: 8290 RETURN TO: ARCO Alaska, Inc. Attn: Maria TrevithiCk Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed c~py of this transmittal. f~/_/o~ I R- 2 7 ,~ LIS Tape and Usting ~'/-? V' I R-2 9 ~ LiS Tape and Usting~P,>'-/.~. ~ . ~/"/°~ I R-2 0 ~,/ LIS Tape and Usting ,~/ -- //' f,'/ I R- 1 7 ~. ? LIS Tape and Usting ,~. j--/-,~ ?/.-~,e~' 1 R-23 ~,/ LIS Tape and Listing Please acknowledge receipt and return 8-31 -91 74904 8-14-91 74854 9-9-91 74922 9-1 9-91 74934 1 0-22-91 751 03 . Receipt .r Acknowledged: - - Date: ................................. RECEIVED Lynn Goettinger State of Alaska ?' N0V 2 7 1991 DISTRIBUTION: Naska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: November 8, 1991 Transmittal #: 8277 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations'File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. R - 2 3 ~ Cement Evaluation Log :.:. 1 0 - 2 9- 91 R 23 ~ Cement Bond Log: ~ :' 10-29-91 1 R - 21 ~ Cement Evaluation Log 1 0 - 21 - 91 1R.21 ~,,-'~ Cement Bond LOg ~ /"'} ./~ ~ 10-21-91 Receipt Acknowledge: /,,~~--,,~--- -~-- Date' Drilling ~' State of~?~(+sepia) Please acknowledge receipt and 7994-12082 7994-12082 7390-10076 7390-10052 NSK ARCO Alaska, Inc. Date: November 1, 1991 Transmittal #: 8274 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk' Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~ ~%~,~11 R-23 ' R-23 CDR 10-22-91 6330-12188 CDN 10-22-91 6330-12188 Receipt Acknowledged' DISTRIBUTION: RECEIVED tel .......... ~OV 04 t991 alas!(a Oil & 8.,'-~s Cuns. CommJssJorl Ancl"~orage D&M Drilling Vendor Package(Johnston) NSK State of Al~~ ARCO Alaska, Inc. Date: November 1, 1991 RETURN TO: ARCO Alaska, inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 8273 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. R 24-~'""": ~ .... "'Ultra Soni~'~ Imager Corrosion Mode 1021 91 1001170 'Alaska 0il & Gas ConS. commission ' MEMORAN DUM State of Alaska ~SKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnle C. Smi~/~- DATE: Oct. 21,1991 CommiSsioner ! - FILE NO: DA. 1021.1 TELEPHONE NO: THRU: (~ SUBJECT: FROM: Doug Amo~ PetroleUm Inspector BOP Test AAI KRU 1R-23 Permit No. 91-101 Kuparuk Rv. Field Wednesday Oct. 16.1991: I traveled this date from AAI PBU to AAI's KRU 1R-23 Well to stand by for the BOP test on Pool Rig No. 7. Thursday ~t.17.1991: The testing commenced this date a~ 6:30 am and was concluded at 9:00 am. As the attached AOGCC BOP Test Report indicates the Choke line HCR valve could not be controlled from the master panel at the accumulator. This was the only failure during the test. Karla Lenz AAI rep. contacted me on 10/20/91 and informed me that the panel had been repaired. In summary, I witnessed the BOP test at AAI's KRU 1R-23 well on Pool Rig No. 7. Attachment, 02-00lA (Rev. 6/89) 20/11/MEMOl.PM3 STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COI~I I SS I ON BOP Test Report OPERATION: Drlg. ~ Wkvr Operator Well / Location: Sec 1'7 T l~-~ R JD~ M Dr1 g contrctr ~;;5;;~ L-- Location (general) / Well stgn~ Housekeeping (general) / Rig_._______ Reserve pit 1// Audio MUD SYSTEMS: Trtp tank Pit gauge Flow monitor Gas detectors BOPE STACK: '" Test Pressure Annular preventer Pipe rams ~Y'~/' ~_ , Z~" 3000 , .Blind rams Choke line valves ~ ,I II DATE //~)//7 /~/ ,TEST: Initial ,~ Weekly L ,, , Other Representative. HCR valve ~J~ I~ Il Kill line valvesd~(' ~ I~ 11 Check valve TEST RESULTS: /, Permit # t-10 I ~:~/j~ ' Casing set ~ ~:~55t~) Rig#..'-7 . Rep,. ~~ ~ O~L~[~ ACCUMULATOR SYSTEM~ Il ~ 5~, ~ Full charge pressure ~.~.~ Press after closure I .~ Remarks: Pump incr clos press 200 pstg Full charge press attained "2 3oo Controls: Master ~ Remote ft psig psig min ~5 sec ~ mtn ~ sec , psig Blind switch cover Y~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly / ~Test Lower Kelly / V('Test Ball type J V~/Test pressure pressure pressure Inside BOP / ~ Test pressure ~ , Choke manifold J ~ Test pressure Number vaives, Number fl anges Adj us ta bl e chokes ~ Hyd~aul tcal ly operated choke ~.- /// 1// Failures Test time ~ ////Z hrs Repair or replacement of faile~ equipment to be made within // the Inspec~or~ and follow wi~h wri~en/FAXed vertfica~ion ~o Co~tssf'on::~ff, ice. itl Distribution: crt9 - AOGCC c - Operator c - Supervisor C.OOq (rev 07/08/91) WITNESS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 27, 1991 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 1R-23 Rev. ARCO Alaska, Inc. Permit No. 91-101 Sur. Loc. 426'FSL, 144'FWL, Sec. 17, T12N, R10E, UM Btmhole Loc. 1018'FSL,2128'FWL, Sec. 9 T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved revised application for permit-to drill the above referenced well. The provisions of the original approved permit dated July 12, 1991 are in effect for this revision. The Commission will advise you of those BOPE tests that it wishes to witness. rely, ,~.,...7 Lonnie C. ~mzth, Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D 1 lb. Type of Well Exploratory r'~ Stratigraphic Test r'~ Development Oil X Re-Entry D Deepen DI Service r'~ Development Gas D Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88', Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25627, ALK 2560 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 426' FSL, 144' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 450' FSL, 1425' FWL, Sec. 9, T12N, R10E, UM 1R-23 #UG30610 At total depth 9. Approximate spud date Amount 1018' FSL, 2128' FWL, Sec. 9, T12N, R10E, UM 9/28/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 R- 1 5 12,275 MD 1,018' @ TD feet 25' @ 800' TVD feet 2560 7,040' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole angle 61° Maximum surface 2457 pslg At total depth ('rVD) 3450 pslg 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Length IVD 'rVD IVD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' :1:200 CF 12.25" 9.625" 36.0# J-55 BTC 6284' 43' 43' 6~327' 4~150' 1200 Sx Permafrost E & 630 Sx Class G 8.5" 7" 26.0# L-80 NSCC 6284' 43' 43' 6,327' 4,150' 270 Sx Class G 7" 26.0# J-55 BTC 5948' 6,327' 4,150' 12,275 7,040' Top 500' above Kuparuk 19. To be completed for Redrill. Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented !-~ , ~,, i.., iM~ajl~dr~pth True Vertical depth Structural KEL, EI VEu Conductor Surface Intermediate Production2 6 3991 Liner Alaska 0ii & Gas Cons. C0mmiSsi0~ Perforation depth: measuredAnchorage true vertical 20. Attachments Filing fee E] Property plat r'] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis ]--] Seabed report r'] 20 AAC 25,050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~'~ ~/~ ~~~'CommissionTitleuse OnlyArea Drillin~l En~linoer Date ~;;)/~__.~ ~'~/ Permit Number I APl number I ^pprova, date ~..,~./~ ¢! I See cover ,etter for c~,/,.../,~.~ 50- O .~-q *" Z**- ,2. ~ <O~__~ other requirements Conditions of approval Samples required [~ Yes ~ No Mud Icg required D Yes ~ No Hydrogen sulfide measures r'l Yes ~ No" Directional survey required ~ Yes [~] Required working pressure for BOPE ' ]--~ 2M [~ 3M ~--] 5M r-] 1OM r'l 15M Other: ~~-~ /Y3.-x.~ ( ,...~_~ ~~ .~ by order of Approved by { / Commissioner the commission Date y~-"~ Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc./"~% Post Office Box 1~ .,~0 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 26, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 1R-18 Deepen API 50-029-22188 Permit Number 91-120 Kuparuk River Unit Well 1R-21 API 50-029-22211 Permit Number 91-113 Kuparuk River Unit Well 1R-23 API 50-029,22200 Permit Number 91-101 Gentlemen: ARCO requests cancellation of permit to drill for Kuparuk River Unit 1R-18 Deepen, and requests approval of revised applications for permit to drill wells 1R-21 (now horizontal to old bottom hole location of 1R-18 Deepen) and 1R-23 (now drilling to old bottom hole location of 1R-21). Drilling operations have not yet started. We appreciate your patience in this matter. If you have any questions, please contact Ellen Fitzpatrick at 263-4638. Sincerely yours, A. Wayne McBride Area Drilling Engineer RECEIVED S E P 2 6 Alaska Oil & Gas Cons. commisSio~ AnchoraOo DRILLING FLUID PROGRAM (1R-23) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System' Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2457 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 R-23 is 1 R-15. As designed, the minimum distance between the two wells would be 25' @ 800' TVD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVED S £ P 6 1991 Alaska Oil & Gas Cons. oommisSior~ Anchorage ARCO ALASKA, Structure' Pad 1R Well' 23 Field · Kuparuk River Unif Location · Norfh Slope, Alaska Ireoted by : jones For: E FITZPATRICK ate plotted : 26-$ep-91 lot Reference is 2.3 Version ~6. oordinotes ore in feet reference slot ~23. rue Vertical Depths ore reference wellhead. I-]/~lll EASTMAN I/_/Z//IIIC H R I STE N S E N 500 _ lO0O- - 1500- -~2000- - 2500- - 3000- 3500- - 4000- ~500- _ 5000- . 5500- 6000- _ 6500- _ 7000- 7500 N 51.05 DEG E 8437' (TO TARGET) oo.oo E a s f - - > 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 B600 7200 7800 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I TDLOCATION: I 1018' I~L, 2128' i~LI ~ I SEC. 9~ TI2N, RIOE J~ SEC. 9~ TI2N~ RIOE J / TARGET / TVD=6538 / TMD= 11242 .~ D£P=8457 / NORTH 5304 ;SURFACE LOCATION: I 496' FSI~ 144' I~L SEC. 17, TIgN, RIOE KOP TVD:500 TMD=500 DEP=O 2.50 7.50 12.50 17.50 ISU~LD 2.5 DEG / 100' 22.50 27.50 32.50 B/ PERMAFROSTTVD=1668 TMD=I726DEP=;520 37.50 42.50 47.50 52.50 57.50 eoc TVD=2505 TMD=2957 DEP:1178 T/ UGNU TVD=2788 TMD:3524 DEP=1691 T/ W SAK SNDS TVD:5475 TMD=4953 DEP=2923 9 5/8"CSG PT TVD=4150 TMD=6527 DEP=4141' AVERAGE ANGLE 60.93 DEG 6600 -4200 A I 5§00 I 3OOO _ 7' -2400 0 _ -~ - -1200 B/ W SAK SNDS TVD=5955 TMD=5921DEP=5787 K-lO TVD=4258 TMD=6549 DEP=4555 RECEIVED K-5 TVD=5993 TMD=10120 DEP=7456 Alaska Oil & Gas Cons. Commission ',Anchorage TARGET TVD=6538 TMD=I1;~4;8 DEP=8437 T/ ZONE C TVD=6656 TMD=11443 OEP=8613 T/ ZONE A WD=6836 TMD==11855 DEP=8973 B/ KUP SNDS WD=6945 TMD:12075 DEP=9165 TD / LOGGING PT WD=7040 TMD=12275 DEP=9340 i i i i i i i i i i i i i i i i i i i i 1 i I i i i i i i i i i i i i i i i i o 50o lo0o ,5oo 2000 2~oo 30o0 3500 4o00 4500 50o0 5500 ~00o ~5oo 7oo0 7~00 8o00 ~500 9oo0 9~oo Scale 1 ' 250.00 Verfical Section on 51.05 azimufh wifh reference 0.00 N, 0.00 E from sial #25 . . . . . . ,, . . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 R-23 Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,327') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (12,275) according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. 50 I I 1 O0 I 150 200 250 300 550 400 450 500 550 I I 70O 9 0 ARCO ALASKA, Inc. Structure: Pad 1R Well ~'~: 21 / 2~ Fleld: Kuoaruk River Unlf Locatlon : North $1ooe. Alaskc 6OO 850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -550 -- A I I O GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 R-23 · · . · . · , . · 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Pool Rig 7. Install divei'ter system· Drill 12-1/4" hole to 9-5/8" surface casing point (6,327') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (12,275) according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. Anchorage , 6 I 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THATAU_ HOLD-DOWN SCREWSARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTFOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)0 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PS1 PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR CEIV D Alaska Oil & Gas 0oli$. Coa missio ~,nchora,qe r~'UPARUK RIVER UN,, 20" DIVERTER SCHEMATIC 51 6 4 ]5 5 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 i ' 0 0 ' . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED SEP 2 6 I991 1. 16" CONDUCTOR Alaska 0ii & Gas Cons. commission 2. SLIP-ON WELD STARTING HEAD Anchorage 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2,000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR GATE VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. G. 20" - 2000 PSI ANNULAR PREVENTER MLP 8/14/91 ALASKA 0IL AND GAS CONSERVATION COMMISSION July 24, 1991 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 re: Kuparuk River Unit 1R-23 ARCO Alaska, Inc. Permit No. 91-101 Sur. Loc. 426'FSL, 144'FWL, Sec. 17, T12N, R10E, UM Btmhole Loc.1742'FNL, 182'FEL, Sec. 16, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. David W.~ John~ton,-Chairman Alaska O~ Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill I~ Redrill Dllb. TypeofWell Exploratory r"! Stratigraphic Test r"l Development Oil I~' Re-EntryD Deepen DI service r"l Development Gas r'l single Zone .1~ Multiple Zone r~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88'~ Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25636, ALK 2569 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 426' FSL, 144' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2030' FNL, 1130' FEL, Sec. 16, T12N, R10E, UM 1R-23 #UG30610 At total depth 9. Approximate spud date Amount 1742' FNL, 182' FEL, Sec. 16, T12N, R10E, UM 8/1 7/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-16 13,420' MD 182' @ TD feet 30' ~ Surface feet 2560 7,153' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 63° Maximum eurface 2457 pslg At total depth (TVD) 3515 pslg 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Length IVD TVD IVD 'rVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' :!:200 CF 12.25" 9.625" 36.0# J-55 BTC 6761' 43' 43' 6r804' 4r150' 1340 Sx Permafrost E & HF-ERW 660 Sx Class G 8.5" 7" 26.0# J-55 BTC 13377 43' 43' 13,420' 7,153' 280SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ ' .~'~ Conductor ~.~ ~'~'[0~0[~ '' :~'' ' !?'':':' SurfaCelntermediate ~~, 'su°3 s~J ~ ~'0 a~l's*l-~' ~l~l[~m03 'su03 se9 ~, t!0 Production Perforation depth: measured BO~eetc~ ~~ ,~ ~~ 20. Attachments Filing fee ~ Property plat r'l Diverte, Sketch '~ Drilling program '~ Drilling fluid program I~1 Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~[/~J ~~/~ T,t,e Aroa Dr,ll,n~ En[t,noor Date " I Commission Use Only I I ISee c°ver letter f°r Permit~/_ ×.~/Number ~0-^P~ numbe~Z?_ ~.~-?-- ~ ~ Approval, date .~ ...~ ~.... ~=/ other re~uirements Oon~i.on. o, =~ov~, ~,~. ~u,~ [:3 ~' ~a' .o =u~ ~o~ ~u,.~ 1:3 ~" ~ .o Hydrogen sulfide measures Yes /1~ No Directional survey required .~ Yes No Required working pressure for BOPE I--] 2M i~ 3M r""l 5M r""l 1OM r"! 15M Other: Appr Commissioner tho commission Date ~ ~ Form 10-401 Rev. 7-24-89 triplicate DRILLING FLUID PROGRAM (1R-23) Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 8.6-10.0 15-35 15-35 50-100' 5-15 15-4O 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drillin(~ Fluid System' T~ndem B~andt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2457 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-23 is 1 R-16. As designed, the minimum distance between the two wells would be 30' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or Kuparuk Field well with open annulus used for disposal. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. ARCO ALASKA, Structure' Pad 1R Well' 23 Field · Kuparuk River Unit Location ' North Slope, Alaska o o o. o 600 1200 _ (")18oo- r-h - 2400- 0 _ ~ 3000- _ ~,- 3600- _ ~ 4200- I--- - 4800- - I V5400- - 6600 - - 7200- ITCCreated by : jones For: E FITZPATRICK Date plotted : 30-Jun-91 Plot Reference is 23 Version ~4. oordinates ore in feet reference slot ~23. rue Vertical Depths are reference wellhead, I-7)~)~I1E AST M A N IZ//J/JIJC H RI ST E N S E N A B~k~r Hughe* company SURFACE LOCATION: 426' FSL, 144' FWL SEC. 17, T12N, RIOE · ¢0o.00 East -- > 8000 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I TD LOCATION: J 1742' FNL, 182' FEL SEC. 16, T12N, RIOF' TARGET LOCATION; J 2030' FNL. 1130' FEL SEC. 16, T12N, RIOE 4000 800 .-~ TARGET '1V0=6648 TMD=12508 OEP=g706 NORTH 2824 EAST 9286 RKB ELEVATION: 88' 250 KOP ~VD=3OOTMD=300 DEP=O N 75 DEG 5 MINE 7150 ~2.5o 9706 (TO TARGET) 17.50 8U~LO 25 BEG / 100' 22.50 ' ~3~ 7452~.00475 B/ PER.FROST WD=1668 TMD:1766 OEP=453 s. s RECEIVED W SAK SNDS ~D=5475 TMD=5512 DEP~5472 B/B W S~ SNDS ~ 3993 TMD 6458 DEP 4493 JUL1. 91991 9 5/8"CS~9 5/8"CS~ 63 ~EG ~ TMD=10655 PEP=8233 Scale 1 ' 300.00 B/ KUP SNDS TVD=7062 TMD=13220 OEP=lO519 TD / LOGGING PT 1VD=7153 TMD=13420 DEP=10697 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section on 73.08 azimuth with reference 0.00 N, 0.00 E from slot #23 650. $00. 550 5O0 450. 400. :350. 300 250 _ 50 100 I 150 200 250 300 z o ' .,~1300 Jl 10..300 0 .. --'9 ~oo )0 .--- ~ 900 ~'?oo O0 350 400 450 500 550 , I ........... J I I I , 300 1 $00 650 6O0 550 500 450 _ 400 _ 350 .300 .25O i I I i I I I i I I I 50 1 O0 1 50 200 250 3~0 350 400 450 500 550 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-23 · · . e . · . · 1 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,804') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Ddll 8-1/2" hole logging while drilling to total depth (13,420') according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. ,I ,6 , 5 4 I3 13 5/8" 5000 BOP STACK ~CCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)O PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 30(X) PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)0 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3(X)0 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3(X)0 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3(X)O PSI X 13-5/8" ~ 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR ~PARUK RIVER UNI~~' 20" DIVERTER SCHEMATIC I I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORN FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) R' CEIVED 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- ~00 PSI DRILLING SPOOL WITH ~O 10" OUTL~S. 5. 1~' HCR BALL VALVES WI~ 1~' DIVERTER LINES, A SINGLE VALVE OPENS AUTO~TICALLY UPON CLOSURE OF ANNU~R PREVE~ER. VALVES CAN BE RE~TELY C~TROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - ~00 PSI ANNU~R PREVENTER SHE 2/6/90 ITEM (1) Fee (2) Loc (3) Admin (4) Casg (5) BOPE (6) Other . . , (6) Addl ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D TE 2. thru 3. 4. [10 & 13] [14 thru 22] [23 thru 28] . 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company . . A~-~O YES Is 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 avabi'able in this pool ............. Is well to be deviated & is well bore,plat included ................... Is operator the onlY affected party .................................. Can permit be approved before 15-day wait .......................... ... Does Operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water.. ................ Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed.... .......................... Is a diverter system required ........................................ Is'drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ' ~ e---e-...ee..e.eee.......~.~.....~.~.~..... Lease & Well ~¢/_ ~¢¢Z7 [ /~ /~-- ~5 NO R~KS / DWJ/' eng i neer i nq:. MTM~__~ LCS ¢ ~:~'~ BEW ..,¢" RAD'~ ,Jl-i~ ' 'ev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' ITEM .Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ['2 th u (3) Admin.~.~./~,. 7//5/,~/'~,/ 9. 1~ ' 10. .... 7-~'.~- ~1/ I 1. [10 ~ 133 12. ...... 13. [1~ thru 22] 15. [23 thru 28] (6) Other '['29 thru' (6) Addl Company Lease $ Well ~ /z2~)~ 2...~' ~,3~' /~d>; //~" 2_,,q NO REMARKS YES ,X Is pemit fee attached .......... , .................................... 2. Is well to be located in a defined pool ................. . ............. 3. Is we]] located proper distance from property line ................... 4. is' we]] located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is we]] to be deviated & is we]]bore plat included ................... 7. Is operator the only affected party .................................. 8. Can pemit be approved before 15-day wait ............................ Does operator have a bond in force ................................... //2 - Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... Is lease n~rnber appropriate .......................................... ~ ...... Does we]l have a unique name & n~rnber ................................ 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. 23. 24. 25. 26. 27. 28. 29. 30. 31. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~oma psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... 32. Additional requirements ............................................. geology' eng i neer i ng,: DWJ-~- MTM,~f LCS, "/?_.~" RPC,~?~. BEW.~ RAD..~ dH/- rev 03/29/91 jo/6.011 INITIAL GEO1 uNIT " ON/OFF POOL CLASS STATUS AREA ~ SHORE / o ., ,'/ Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~IS :?ape':. Veri. ftcetlon b[st=~n; chlumberger Alas:~a Comput~n~ Center DAT~ : 92/01/22 ORIGIN : FLIC R~E[, NAME .. : 75103 CON?iNUATiON # .: PREVIOUS REEL : COMMENT : ARCO A ASKA I,¢.., UPARuKRIv R, O".O . 200"O0 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 92/01/22 TAPE,NAME : 75:10~ C~TINUATION # : ~ PREVIOUS TAPE ~ CON'~ENT = ARCO ALASKA INC., IR-'2], KUPA:RUK, RIVER,. 50.029.22200.00 F~'LE NA~E! : EDIT ,.,00! $£RVIC£ : F~iC V~SION : 00IA06 DATE' : 92/01/22 FILE TYPE:: LAST FiLE : ******************************************************************************** , , , FILg - EDIT,O01 ARCO ALASKA KUPARUK RIVER R-23 0"029-22200 MAIN PASS LWD LOG DATA THE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FRO~ 'RHOB ~qAX' DATA SA~P.LED EVERY -'5000 FEET DATA INCLUDED TOOL EXTENSION TYPE USED RG8 .LWD ND$ ,SWD TOOL NANE LOGGING NHIbE DRILLING RESISTIVITY/GR 6330' TO 12123' LOGGING NHILE DRILLING NEUTRON/DENSITY 6330· TO~2057" 3NOZ ease& e~d~e~ a~e~ pn~ &~3O so~$IA p;nlJ ~u~T$~O ~ d~ AjQ qd p~nt~ ou~T~O ~eb~oq - q~deO Te~o~ '8~t~ ~ ~aTT'T~Q - q~daO Te~o~ °88~T &~ eo *~ed ~o uoi~eAe~ o &a aa3 ~.$qmnN ~eP~O e;IA~eg .£8~66g NOg A~OD 3d'Oqg H&~ON N/10D e~uea · .eqmnN ~et~e9' aV ' ' 00~=6~0-0~. aweN &ueowo~ N. v' ~. 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