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216-104
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-13A KUPARUK RIV UNIT 2S-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 2S-13A 50-103-20720-01-00 216-104-0 W SPT 6271 2161040 3800 2240 2240 2240 2240 670 953 957 958 REQVAR P Sully Sullivan 7/14/2024 MIT-IA to MAIP every 2 years per AIO 2C.069 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-13A Inspection Date: Tubing OA Packer Depth 1180 4010 3920 3900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717073111 BBL Pumped:4.3 BBL Returned:4 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9MIT-IA AIO 2C.069 James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:05:39 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-13A KUPARUK RIV UNIT 2S-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 2S-13A 50-103-20720-01-00 216-104-0 W SPT 6271 2161040 1200 2240 2240 2240 2240 630 1990 1960 1960 REQVAR P Sully Sullivan 7/14/2024 test every 2 years to no less than 1200 psi per AIO 2C.069 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-13A Inspection Date: Tubing OA Packer Depth 1200 1400 1420 1400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240717073948 BBL Pumped:3.9 BBL Returned:3.4 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 0,72$ 9 9 AIO 2C.069 0,72$ James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:14:04 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2S-13A (PTD 216-104) Date:Tuesday, July 2, 2024 8:19:32 AM Attachments:image001.png 2S-13A.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, June 27, 2024 11:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2S-13A (PTD 216-104) Hi Chris, KRU 2S-13 (PTD 216-104) has completed the 30 day monitor period on water injection. The IA pressure trends stabilized and maintained below the DNE of 2000 psi on water injection. CPAI intends to amend the AA to water injection only. Below is the current 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:2S-13A 1/16/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY. Pulled Plug2S-13A4/15/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for continued WAG injection with known TxIA communication on gas 6/4/2019 jbyrne Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread TIE BACK CASING 7 5/8 6.88 26.4 8,691.4 5,704.8 29.70 L-80 Hyd563 INTRM LINER 7 5/8 6.88 8,682.2 10,398.2 6,350.5 29.70 L80 Hyd 563 A-3 SLOTTED LINER 4 1/2 3.96 9,968.7 16,829.0 6,251.6 11.60 L-80 IBTM LEM / ZXP 4 1/2 3.96 9,985.1 10,285.9 6,341.0 12.60 L-80 IBTM A3 LINER w/ PERF PUPS 4 1/2 3.96 10,221.9 16,895.3 6,250.1 12.60 L-80 IBT-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.6 Set Depth … 10,019.9 Set Depth … 6,283.2 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-m ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.5 35.5 0.02 HANGER 13.500 Cameron 11" x 4-1/2" Tubing Hanger Camero n PN: 2217576 -42-02, SN 1204458 34-1 3.900 3,521.03,010.9 54.97 GAS LIFT 6.640 4-1/2" x 1" Camco KBMG GLM ( 3010' TVD) Camco KBMG3.860 8,797.2 5,762.4 57.69 GAS LIFT 6.640 4-1/2" x 1" Camco KBMG GLM ( 5761' TVD) Camco KBMG3.860 9,918.86,250.7 69.84 NIPPLE 4.500 Camco 3.81” DB nipple Camco PN: 33574- 000- 25019, SN: N15N10 65 3.813 9,991.5 6,274.6 71.90 LOCATOR 5.370 Baker 4-1/2" Locator Baker PN: H45001 0074, Control # 1045875 46 3.880 9,993.3 6,275.1 71.95 SEAL ASSY 4.750 Baker 4-1/2" GBH-22 Seal Assy Baker PN: H45001 0074, Control # 1045875 46 3.880 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,521.0 3,010.9 54.97 1 GAS LIFT DMY BK 1 0.06/11/2017 Schlumb erger 0.000 8,797.2 5,762.4 57.69 2 GAS LIFT DMY BK 1 0.0 4/15/2024 Schlumb erger 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,680.7 5,698.9 56.22 LOCATOR 7.625 Baker No-Go (Locate at bottom end) 6.770 9,985.1 6,272.6 71.71 Packer 6.570 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 SN # 105610275 Baker ZXP, PN: H296-45- 0131, SN# 105610275 4.930 10,023.96,284.4 72.83 Crossover (XO) Bushing 5.500 Reducing Crossover sub 5½" H563 B x 4-1/2" IBTM 3.940 10,032.66,286.9 73.08 Triple connect bushing 5.580 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 105415277-01 Baker Hook LEM, PN: H289- 18-0032, SN# 105415277- 01 3.700 10,035.8 6,287.9 73.18 Triple connect bushing 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger) 3.688 10,232.66,333.380.57 Nipple - DB, XN, DS, D 5.200 Camco 4-1/2" x 3.563" DB-6 Nipple SN# N15N1151 Camco DB-6, PN: 100101390, SN# N15N1151 3.563 10,244.4 6,335.2 81.06 XO Threads 4.500 Tubing XO joint 4-1/2" 12.6 ppf L- 80 IBTM, IBTM box x ST-L pin 3.970 8,682.2 5,699.8 56.24 PACKER 9.610 7-5/8" X 10-3/4"(2RH) ZXP w/ HD Liner Top Packer Baker ZXP Part # H296-29- NA14, Control No.: 105429496 6.760 10,266.26,338.4 81.97 Landing Collar 8.500 BHI 7-5/8" Landing Collar, Hydril 563 Baker CPAI # 13726990 6.875 MULTIPLE LATERALS, 2S-13A, 4/16/2024 5:23:44 AM Vertical schematic (actual) A3 LINER w/ PERF PUPS; 10,221.9-16,895.3 Float Shoe; 16,893.3-16,895.3 A-3 SLOTTED LINER; 9,968.7- 16,829.0 SHOE; 16,827.1-16,829.0 Perf Pups; 16,760.2-16,770.0 Perf Pups; 16,667.0-16,676.8 Perf Pups; 16,531.7-16,541.5 Perf Pups; 16,396.2-16,406.0 Perf Pups; 16,260.4-16,270.2 Perf Pups; 16,124.7-16,134.5 Perf Pups; 15,989.1-15,998.9 Perf Pups; 15,856.6-15,866.5 Perf Pups; 15,727.4-15,737.2 Perf Pups; 15,597.9-15,607.7 Perf Pups; 15,466.3-15,476.1 Perf Pups; 15,336.2-15,346.1 Perf Pups; 15,205.9-15,215.7 Perf Pups; 15,076.8-15,086.6 SWELL PACKER; 14,977.1- 14,982.7 SWELL PACKER; 14,578.5- 14,584.2 Perf Pups; 14,553.7-14,563.5 Perf Pups; 14,423.5-14,433.3 SWELL PACKER; 14,392.3- 14,408.3 Perf Pups; 14,292.5-14,302.4 Perf Pups; 14,163.7-14,173.5 Perf Pups; 14,032.7-14,042.5 Perf Pups; 13,901.7-13,911.6 Perf Pups; 13,770.7-13,780.5 Perf Pups; 13,639.5-13,649.4 Perf Pups; 13,510.4-13,520.2 Perf Pups; 13,380.7-13,390.5 Perf Pups; 13,248.4-13,258.2 Perf Pups; 13,117.4-13,127.3 Perf Pups; 12,989.7-12,999.6 Perf Pups; 12,859.4-12,869.2 Perf Pups; 12,728.9-12,738.7 Perf Pups; 12,599.1-12,608.9 Perf Pups; 12,468.2-12,478.0 Perf Pups; 12,337.2-12,347.0 Perf Pups; 12,206.4-12,216.2 Perf Pups; 12,075.3-12,085.1 Perf Pups; 11,944.0-11,953.8 Perf Pups; 11,812.7-11,822.5 Perf Pups; 11,681.8-11,691.7 Perf Pups; 11,550.8-11,560.6 Perf Pups; 11,419.2-11,429.1 Perf Pups; 11,288.2-11,298.0 Perf Pups; 11,160.3-11,170.2 Perf Pups; 11,029.5-11,039.3 Perf Pups; 10,898.7-10,908.5 Perf Pups; 10,767.6-10,777.4 Perf Pups; 10,636.2-10,646.0 Perf Pups; 10,506.7-10,516.5 SWELL PACKER; 10,463.8- 10,479.9 SWELL PACKER; 10,456.6- 10,463.3 INTRM LINER; 8,682.2-10,398.2 Float Shoe; 10,396.0-10,398.2 LEM / ZXP; 9,985.1-10,285.9 Seal Assembly; 10,282.6- 10,285.9 SBE (Seal Bore Extension); 10,265.0-10,284.7 Landing Collar; 10,266.2- 10,269.6 XO Threads; 10,244.4-10,282.6 HANGER; 10,244.6-10,254.4 NIPPLE; 10,241.8-10,244.6 Tubing; 10,234.6-10,244.4 Nipple - DB, XN, DS, D; 10,232.6-10,234.6 Liner Top Packer; 10,221.9- 10,241.8 Tubing - Pup; 10,222.8-10,232.6 Space Out - Pup; 10,220.7- 10,222.8 Tubing; 10,060.3-10,220.7 Triple connect bushing; 10,035.8 -10,060.3 A4 LINER; 10,024.0-16,945.9 Triple connect bushing; 10,032.6 -10,035.8 HANGER; 10,024.0-10,047.9 Tubing; 10,028.0-10,032.6 Tubing; 10,025.2-10,028.0 Crossover (XO) Bushing; 10,023.9-10,025.2 Liner - Pup; 10,022.1-10,026.0 XO Threads ; 10,020.7-10,022.1 SBE (Seal Bore Extension); 10,005.0-10,023.9 SBE; 10,001.0-10,020.7 SEAL ASSY; 9,993.2 HANGER; 9,991.2-10,001.0 Packer; 9,985.1-10,005.0 LOCATOR; 9,991.5 PACKOFF; 9,988.6-9,991.2 PACKER; 9,968.7-9,988.6 NIPPLE; 9,918.8 GAS LIFT; 8,797.2 INTERMEDIATE LINER; 2,693.9 -9,318.0 TIE BACK CASING; 26.4- 8,691.4 SEAL ASSY; 8,681.8-8,691.4 GAS LIFT; 3,521.0 SURFACE; 27.3-2,835.0 SHOE; 2,832.5-2,835.0 XO Threads (Casing); 2,713.4- 2,714.8 Liner Top Packer; 2,693.9- 2,713.4 CONDUCTOR; 27.5-107.5 HANGER; 35.5 HANGER; 27.3-28.4 HANGER; 26.4-26.9 KUP INJ KB-Grd (ft) 27.50 RR Date 2/6/2016 Other Elev… Elevation Hi t 2S-13A ... TD Act Btm (ftKB) 16,905.3 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032072001 Wellbore Status INJ Max Angle & MD Incl (°) 93.12 MD (ftKB) 10,819.52 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,968.7 6,267.4 71.25 PACKER 6.500 HRD-E ZXP Liner top packer 5 1/2" x 7 5/8" L-80 5 1/2" Hydril 563 pin Baker 105545470 5.750 9,988.66,273.7 71.81 PACKOFF 5.500 RS packoff Seal Nipple 5 1/2" L- 80 5 1/2" Hydril 563 box X box Baker 1055489354.870 10,020.7 6,283.4 72.74 XO Threads 4.500 XO Sub 5.5" Hydril 563 box X 4.5" IBT pin 3.940 10,463.96,352.4 89.32 SWELL PACKER 4.500 4½" IBTM Swell Packer Baker 6.37" OD 5 SN# 049169-001-24 (A3 @ 10434') Baker 049169-001 -24 3.950 14,392.3 6,295.1 87.81 SWELL PACKER 4.500 4½" IBTM Swell Packer Baker 6.37" OD SN# 049169-001-15 ( Fault @ 14620') Baker 049169-001 -15 3.950 10,241.8 6,334.7 80.96 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 14# L-80 Hyd 563 box x box BakerH294- 010656, Control No.: 105785124 4.860 10,456.6 6,352.3 89.13 SWELL PACKER 6.360 Baker -- "Swell Packer #3- "C" 6.38" OD SN: 049169-001-11 BakerH301-87- 0397, Ser # 049169-001 -11, compound 920/83 3.960 14,578.66,300.988.11 SWELL PACKER 5.760 Tam -- "Swell Packer #2- "B" 5.7" OD SN:50151812-01 Tam PN: 450-FR -02- 10290500, SN 50151812- 01 3.958 14,977.1 6,306.4 90.36 SWELL PACKER 5.760 Tam-- "Swell Packer #1- "A" 5.75" OD SN: 50151812-02 TamPN: 450-FR -02- 10290500, SN 50151812- 02 3.958 MULTIPLE LATERALS, 2S-13A, 4/16/2024 5:23:46 AM Vertical schematic (actual) A3 LINER w/ PERF PUPS; 10,221.9-16,895.3 Float Shoe; 16,893.3-16,895.3 A-3 SLOTTED LINER; 9,968.7- 16,829.0 SHOE; 16,827.1-16,829.0 Perf Pups; 16,760.2-16,770.0 Perf Pups; 16,667.0-16,676.8 Perf Pups; 16,531.7-16,541.5 Perf Pups; 16,396.2-16,406.0 Perf Pups; 16,260.4-16,270.2 Perf Pups; 16,124.7-16,134.5 Perf Pups; 15,989.1-15,998.9 Perf Pups; 15,856.6-15,866.5 Perf Pups; 15,727.4-15,737.2 Perf Pups; 15,597.9-15,607.7 Perf Pups; 15,466.3-15,476.1 Perf Pups; 15,336.2-15,346.1 Perf Pups; 15,205.9-15,215.7 Perf Pups; 15,076.8-15,086.6 SWELL PACKER; 14,977.1- 14,982.7 SWELL PACKER; 14,578.5- 14,584.2 Perf Pups; 14,553.7-14,563.5 Perf Pups; 14,423.5-14,433.3 SWELL PACKER; 14,392.3- 14,408.3 Perf Pups; 14,292.5-14,302.4 Perf Pups; 14,163.7-14,173.5 Perf Pups; 14,032.7-14,042.5 Perf Pups; 13,901.7-13,911.6 Perf Pups; 13,770.7-13,780.5 Perf Pups; 13,639.5-13,649.4 Perf Pups; 13,510.4-13,520.2 Perf Pups; 13,380.7-13,390.5 Perf Pups; 13,248.4-13,258.2 Perf Pups; 13,117.4-13,127.3 Perf Pups; 12,989.7-12,999.6 Perf Pups; 12,859.4-12,869.2 Perf Pups; 12,728.9-12,738.7 Perf Pups; 12,599.1-12,608.9 Perf Pups; 12,468.2-12,478.0 Perf Pups; 12,337.2-12,347.0 Perf Pups; 12,206.4-12,216.2 Perf Pups; 12,075.3-12,085.1 Perf Pups; 11,944.0-11,953.8 Perf Pups; 11,812.7-11,822.5 Perf Pups; 11,681.8-11,691.7 Perf Pups; 11,550.8-11,560.6 Perf Pups; 11,419.2-11,429.1 Perf Pups; 11,288.2-11,298.0 Perf Pups; 11,160.3-11,170.2 Perf Pups; 11,029.5-11,039.3 Perf Pups; 10,898.7-10,908.5 Perf Pups; 10,767.6-10,777.4 Perf Pups; 10,636.2-10,646.0 Perf Pups; 10,506.7-10,516.5 SWELL PACKER; 10,463.8- 10,479.9 SWELL PACKER; 10,456.6- 10,463.3 INTRM LINER; 8,682.2-10,398.2 Float Shoe; 10,396.0-10,398.2 LEM / ZXP; 9,985.1-10,285.9 Seal Assembly; 10,282.6- 10,285.9 SBE (Seal Bore Extension); 10,265.0-10,284.7 Landing Collar; 10,266.2- 10,269.6 XO Threads; 10,244.4-10,282.6 HANGER; 10,244.6-10,254.4 NIPPLE; 10,241.8-10,244.6 Tubing; 10,234.6-10,244.4 Nipple - DB, XN, DS, D; 10,232.6-10,234.6 Liner Top Packer; 10,221.9- 10,241.8 Tubing - Pup; 10,222.8-10,232.6 Space Out - Pup; 10,220.7- 10,222.8 Tubing; 10,060.3-10,220.7 Triple connect bushing; 10,035.8 -10,060.3 A4 LINER; 10,024.0-16,945.9 Triple connect bushing; 10,032.6 -10,035.8 HANGER; 10,024.0-10,047.9 Tubing; 10,028.0-10,032.6 Tubing; 10,025.2-10,028.0 Crossover (XO) Bushing; 10,023.9-10,025.2 Liner - Pup; 10,022.1-10,026.0 XO Threads ; 10,020.7-10,022.1 SBE (Seal Bore Extension); 10,005.0-10,023.9 SBE; 10,001.0-10,020.7 SEAL ASSY; 9,993.2 HANGER; 9,991.2-10,001.0 Packer; 9,985.1-10,005.0 LOCATOR; 9,991.5 PACKOFF; 9,988.6-9,991.2 PACKER; 9,968.7-9,988.6 NIPPLE; 9,918.8 GAS LIFT; 8,797.2 INTERMEDIATE LINER; 2,693.9 -9,318.0 TIE BACK CASING; 26.4- 8,691.4 SEAL ASSY; 8,681.8-8,691.4 GAS LIFT; 3,521.0 SURFACE; 27.3-2,835.0 SHOE; 2,832.5-2,835.0 XO Threads (Casing); 2,713.4- 2,714.8 Liner Top Packer; 2,693.9- 2,713.4 CONDUCTOR; 27.5-107.5 HANGER; 35.5 HANGER; 27.3-28.4 HANGER; 26.4-26.9 KUP INJ 2S-13A ... WELLNAME WELLBORE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Date:Wednesday, May 22, 2024 9:26:52 AM Attachments:image001.png AnnComm Surveillance TIO for 2S-13A.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, May 22, 2024 9:23 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris- KRU 2S-13A (PTD #216-104) has completed the 30 day monitor period on gas injection. Unfortunately, the IA was unable to sustain pressure beneath the DNE of 2400 psi and required more than two bleeds to manage the pressure. The well no longer meets the operational requirements of AIO 2C.069. CPAI intends to WAG the well to water injection for a 30 day monitor period to verify IA integrity while on water injection. Upon the completion of the monitor period, CPAI will submit the proper notifications for repair or an AA amendment to water injection only. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, April 17, 2024 12:51 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris- KRU 2S-13A (PTD 216-104) operating under AIO 2C.069 has had the IA circulated out with clean fluids. CPAI intends to bring the well back on gas injection for a 30 day monitor period to investigate the ability for the IA to remain under the DNE of 2400 psi. Depending on the results of the 30 day monitor period the proper paperwork for continued injection or repair will be submitted at that time. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Byrne, Jan Sent: Monday, March 4, 2024 11:39 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris, KRU 2S-13A (PTD 216-104) (AIO 2C.069) exceeded the allowed two non-thermal related IA pressure bleeds per month. The well will be shut in and freeze protected while a path forward is determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:2S-13A 1/16/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY. Pulled Plug2S-13A4/15/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for continued WAG injection with known TxIA communication on gas 6/4/2019 jbyrne Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread TIE BACK CASING 7 5/8 6.88 26.4 8,691.4 5,704.8 29.70 L-80 Hyd563 INTRM LINER 7 5/8 6.88 8,682.2 10,398.2 6,350.5 29.70 L80 Hyd 563 A-3 SLOTTED LINER 4 1/2 3.96 9,968.7 16,829.0 6,251.6 11.60 L-80 IBTM LEM / ZXP 4 1/2 3.96 9,985.1 10,285.9 6,341.0 12.60 L-80 IBTM A3 LINER w/ PERF PUPS 4 1/2 3.96 10,221.9 16,895.3 6,250.1 12.60 L-80 IBT-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.6 Set Depth … 10,019.9 Set Depth … 6,283.2 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-m ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.5 35.5 0.02 HANGER 13.500 Cameron 11" x 4-1/2" Tubing Hanger Camero n PN: 2217576 -42-02, SN 1204458 34-1 3.900 3,521.03,010.9 54.97 GAS LIFT 6.640 4-1/2" x 1" Camco KBMG GLM ( 3010' TVD) Camco KBMG3.860 8,797.2 5,762.4 57.69 GAS LIFT 6.640 4-1/2" x 1" Camco KBMG GLM ( 5761' TVD) Camco KBMG3.860 9,918.86,250.7 69.84 NIPPLE 4.500 Camco 3.81” DB nipple Camco PN: 33574- 000- 25019, SN: N15N10 65 3.813 9,991.5 6,274.6 71.90 LOCATOR 5.370 Baker 4-1/2" Locator Baker PN: H45001 0074, Control # 1045875 46 3.880 9,993.3 6,275.1 71.95 SEAL ASSY 4.750 Baker 4-1/2" GBH-22 Seal Assy Baker PN: H45001 0074, Control # 1045875 46 3.880 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,521.0 3,010.9 54.97 1 GAS LIFT DMY BK 1 0.06/11/2017 Schlumb erger 0.000 8,797.2 5,762.4 57.69 2 GAS LIFT DMY BK 1 0.0 4/15/2024 Schlumb erger 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,680.7 5,698.9 56.22 LOCATOR 7.625 Baker No-Go (Locate at bottom end) 6.770 9,985.1 6,272.6 71.71 Packer 6.570 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 SN # 105610275 Baker ZXP, PN: H296-45- 0131, SN# 105610275 4.930 10,023.96,284.4 72.83 Crossover (XO) Bushing 5.500 Reducing Crossover sub 5½" H563 B x 4-1/2" IBTM 3.940 10,032.66,286.9 73.08 Triple connect bushing 5.580 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 105415277-01 Baker Hook LEM, PN: H289- 18-0032, SN# 105415277- 01 3.700 10,035.8 6,287.9 73.18 Triple connect bushing 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger) 3.688 10,232.66,333.380.57 Nipple - DB, XN, DS, D 5.200 Camco 4-1/2" x 3.563" DB-6 Nipple SN# N15N1151 Camco DB-6, PN: 100101390, SN# N15N1151 3.563 10,244.4 6,335.2 81.06 XO Threads 4.500 Tubing XO joint 4-1/2" 12.6 ppf L- 80 IBTM, IBTM box x ST-L pin 3.970 8,682.2 5,699.8 56.24 PACKER 9.610 7-5/8" X 10-3/4"(2RH) ZXP w/ HD Liner Top Packer Baker ZXP Part # H296-29- NA14, Control No.: 105429496 6.760 10,266.26,338.4 81.97 Landing Collar 8.500 BHI 7-5/8" Landing Collar, Hydril 563 Baker CPAI # 13726990 6.875 MULTIPLE LATERALS, 2S-13A, 4/16/2024 5:23:44 AM Vertical schematic (actual) A3 LINER w/ PERF PUPS; 10,221.9-16,895.3 Float Shoe; 16,893.3-16,895.3 A-3 SLOTTED LINER; 9,968.7- 16,829.0 SHOE; 16,827.1-16,829.0 Perf Pups; 16,760.2-16,770.0 Perf Pups; 16,667.0-16,676.8 Perf Pups; 16,531.7-16,541.5 Perf Pups; 16,396.2-16,406.0 Perf Pups; 16,260.4-16,270.2 Perf Pups; 16,124.7-16,134.5 Perf Pups; 15,989.1-15,998.9 Perf Pups; 15,856.6-15,866.5 Perf Pups; 15,727.4-15,737.2 Perf Pups; 15,597.9-15,607.7 Perf Pups; 15,466.3-15,476.1 Perf Pups; 15,336.2-15,346.1 Perf Pups; 15,205.9-15,215.7 Perf Pups; 15,076.8-15,086.6 SWELL PACKER; 14,977.1- 14,982.7 SWELL PACKER; 14,578.5- 14,584.2 Perf Pups; 14,553.7-14,563.5 Perf Pups; 14,423.5-14,433.3 SWELL PACKER; 14,392.3- 14,408.3 Perf Pups; 14,292.5-14,302.4 Perf Pups; 14,163.7-14,173.5 Perf Pups; 14,032.7-14,042.5 Perf Pups; 13,901.7-13,911.6 Perf Pups; 13,770.7-13,780.5 Perf Pups; 13,639.5-13,649.4 Perf Pups; 13,510.4-13,520.2 Perf Pups; 13,380.7-13,390.5 Perf Pups; 13,248.4-13,258.2 Perf Pups; 13,117.4-13,127.3 Perf Pups; 12,989.7-12,999.6 Perf Pups; 12,859.4-12,869.2 Perf Pups; 12,728.9-12,738.7 Perf Pups; 12,599.1-12,608.9 Perf Pups; 12,468.2-12,478.0 Perf Pups; 12,337.2-12,347.0 Perf Pups; 12,206.4-12,216.2 Perf Pups; 12,075.3-12,085.1 Perf Pups; 11,944.0-11,953.8 Perf Pups; 11,812.7-11,822.5 Perf Pups; 11,681.8-11,691.7 Perf Pups; 11,550.8-11,560.6 Perf Pups; 11,419.2-11,429.1 Perf Pups; 11,288.2-11,298.0 Perf Pups; 11,160.3-11,170.2 Perf Pups; 11,029.5-11,039.3 Perf Pups; 10,898.7-10,908.5 Perf Pups; 10,767.6-10,777.4 Perf Pups; 10,636.2-10,646.0 Perf Pups; 10,506.7-10,516.5 SWELL PACKER; 10,463.8- 10,479.9 SWELL PACKER; 10,456.6- 10,463.3 INTRM LINER; 8,682.2-10,398.2 Float Shoe; 10,396.0-10,398.2 LEM / ZXP; 9,985.1-10,285.9 Seal Assembly; 10,282.6- 10,285.9 SBE (Seal Bore Extension); 10,265.0-10,284.7 Landing Collar; 10,266.2- 10,269.6 XO Threads; 10,244.4-10,282.6 HANGER; 10,244.6-10,254.4 NIPPLE; 10,241.8-10,244.6 Tubing; 10,234.6-10,244.4 Nipple - DB, XN, DS, D; 10,232.6-10,234.6 Liner Top Packer; 10,221.9- 10,241.8 Tubing - Pup; 10,222.8-10,232.6 Space Out - Pup; 10,220.7- 10,222.8 Tubing; 10,060.3-10,220.7 Triple connect bushing; 10,035.8 -10,060.3 A4 LINER; 10,024.0-16,945.9 Triple connect bushing; 10,032.6 -10,035.8 HANGER; 10,024.0-10,047.9 Tubing; 10,028.0-10,032.6 Tubing; 10,025.2-10,028.0 Crossover (XO) Bushing; 10,023.9-10,025.2 Liner - Pup; 10,022.1-10,026.0 XO Threads ; 10,020.7-10,022.1 SBE (Seal Bore Extension); 10,005.0-10,023.9 SBE; 10,001.0-10,020.7 SEAL ASSY; 9,993.2 HANGER; 9,991.2-10,001.0 Packer; 9,985.1-10,005.0 LOCATOR; 9,991.5 PACKOFF; 9,988.6-9,991.2 PACKER; 9,968.7-9,988.6 NIPPLE; 9,918.8 GAS LIFT; 8,797.2 INTERMEDIATE LINER; 2,693.9 -9,318.0 TIE BACK CASING; 26.4- 8,691.4 SEAL ASSY; 8,681.8-8,691.4 GAS LIFT; 3,521.0 SURFACE; 27.3-2,835.0 SHOE; 2,832.5-2,835.0 XO Threads (Casing); 2,713.4- 2,714.8 Liner Top Packer; 2,693.9- 2,713.4 CONDUCTOR; 27.5-107.5 HANGER; 35.5 HANGER; 27.3-28.4 HANGER; 26.4-26.9 KUP INJ KB-Grd (ft) 27.50 RR Date 2/6/2016 Other Elev… Elevation Hi t 2S-13A ... TD Act Btm (ftKB) 16,905.3 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032072001 Wellbore Status INJ Max Angle & MD Incl (°) 93.12 MD (ftKB) 10,819.52 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,968.7 6,267.4 71.25 PACKER 6.500 HRD-E ZXP Liner top packer 5 1/2" x 7 5/8" L-80 5 1/2" Hydril 563 pin Baker 105545470 5.750 9,988.66,273.7 71.81 PACKOFF 5.500 RS packoff Seal Nipple 5 1/2" L- 80 5 1/2" Hydril 563 box X box Baker 1055489354.870 10,020.7 6,283.4 72.74 XO Threads 4.500 XO Sub 5.5" Hydril 563 box X 4.5" IBT pin 3.940 10,463.96,352.4 89.32 SWELL PACKER 4.500 4½" IBTM Swell Packer Baker 6.37" OD 5 SN# 049169-001-24 (A3 @ 10434') Baker 049169-001 -24 3.950 14,392.3 6,295.1 87.81 SWELL PACKER 4.500 4½" IBTM Swell Packer Baker 6.37" OD SN# 049169-001-15 ( Fault @ 14620') Baker 049169-001 -15 3.950 10,241.8 6,334.7 80.96 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 14# L-80 Hyd 563 box x box BakerH294- 010656, Control No.: 105785124 4.860 10,456.6 6,352.3 89.13 SWELL PACKER 6.360 Baker -- "Swell Packer #3- "C" 6.38" OD SN: 049169-001-11 BakerH301-87- 0397, Ser # 049169-001 -11, compound 920/83 3.960 14,578.66,300.988.11 SWELL PACKER 5.760 Tam -- "Swell Packer #2- "B" 5.7" OD SN:50151812-01 Tam PN: 450-FR -02- 10290500, SN 50151812- 01 3.958 14,977.1 6,306.4 90.36 SWELL PACKER 5.760 Tam-- "Swell Packer #1- "A" 5.75" OD SN: 50151812-02 TamPN: 450-FR -02- 10290500, SN 50151812- 02 3.958 MULTIPLE LATERALS, 2S-13A, 4/16/2024 5:23:46 AM Vertical schematic (actual) A3 LINER w/ PERF PUPS; 10,221.9-16,895.3 Float Shoe; 16,893.3-16,895.3 A-3 SLOTTED LINER; 9,968.7- 16,829.0 SHOE; 16,827.1-16,829.0 Perf Pups; 16,760.2-16,770.0 Perf Pups; 16,667.0-16,676.8 Perf Pups; 16,531.7-16,541.5 Perf Pups; 16,396.2-16,406.0 Perf Pups; 16,260.4-16,270.2 Perf Pups; 16,124.7-16,134.5 Perf Pups; 15,989.1-15,998.9 Perf Pups; 15,856.6-15,866.5 Perf Pups; 15,727.4-15,737.2 Perf Pups; 15,597.9-15,607.7 Perf Pups; 15,466.3-15,476.1 Perf Pups; 15,336.2-15,346.1 Perf Pups; 15,205.9-15,215.7 Perf Pups; 15,076.8-15,086.6 SWELL PACKER; 14,977.1- 14,982.7 SWELL PACKER; 14,578.5- 14,584.2 Perf Pups; 14,553.7-14,563.5 Perf Pups; 14,423.5-14,433.3 SWELL PACKER; 14,392.3- 14,408.3 Perf Pups; 14,292.5-14,302.4 Perf Pups; 14,163.7-14,173.5 Perf Pups; 14,032.7-14,042.5 Perf Pups; 13,901.7-13,911.6 Perf Pups; 13,770.7-13,780.5 Perf Pups; 13,639.5-13,649.4 Perf Pups; 13,510.4-13,520.2 Perf Pups; 13,380.7-13,390.5 Perf Pups; 13,248.4-13,258.2 Perf Pups; 13,117.4-13,127.3 Perf Pups; 12,989.7-12,999.6 Perf Pups; 12,859.4-12,869.2 Perf Pups; 12,728.9-12,738.7 Perf Pups; 12,599.1-12,608.9 Perf Pups; 12,468.2-12,478.0 Perf Pups; 12,337.2-12,347.0 Perf Pups; 12,206.4-12,216.2 Perf Pups; 12,075.3-12,085.1 Perf Pups; 11,944.0-11,953.8 Perf Pups; 11,812.7-11,822.5 Perf Pups; 11,681.8-11,691.7 Perf Pups; 11,550.8-11,560.6 Perf Pups; 11,419.2-11,429.1 Perf Pups; 11,288.2-11,298.0 Perf Pups; 11,160.3-11,170.2 Perf Pups; 11,029.5-11,039.3 Perf Pups; 10,898.7-10,908.5 Perf Pups; 10,767.6-10,777.4 Perf Pups; 10,636.2-10,646.0 Perf Pups; 10,506.7-10,516.5 SWELL PACKER; 10,463.8- 10,479.9 SWELL PACKER; 10,456.6- 10,463.3 INTRM LINER; 8,682.2-10,398.2 Float Shoe; 10,396.0-10,398.2 LEM / ZXP; 9,985.1-10,285.9 Seal Assembly; 10,282.6- 10,285.9 SBE (Seal Bore Extension); 10,265.0-10,284.7 Landing Collar; 10,266.2- 10,269.6 XO Threads; 10,244.4-10,282.6 HANGER; 10,244.6-10,254.4 NIPPLE; 10,241.8-10,244.6 Tubing; 10,234.6-10,244.4 Nipple - DB, XN, DS, D; 10,232.6-10,234.6 Liner Top Packer; 10,221.9- 10,241.8 Tubing - Pup; 10,222.8-10,232.6 Space Out - Pup; 10,220.7- 10,222.8 Tubing; 10,060.3-10,220.7 Triple connect bushing; 10,035.8 -10,060.3 A4 LINER; 10,024.0-16,945.9 Triple connect bushing; 10,032.6 -10,035.8 HANGER; 10,024.0-10,047.9 Tubing; 10,028.0-10,032.6 Tubing; 10,025.2-10,028.0 Crossover (XO) Bushing; 10,023.9-10,025.2 Liner - Pup; 10,022.1-10,026.0 XO Threads ; 10,020.7-10,022.1 SBE (Seal Bore Extension); 10,005.0-10,023.9 SBE; 10,001.0-10,020.7 SEAL ASSY; 9,993.2 HANGER; 9,991.2-10,001.0 Packer; 9,985.1-10,005.0 LOCATOR; 9,991.5 PACKOFF; 9,988.6-9,991.2 PACKER; 9,968.7-9,988.6 NIPPLE; 9,918.8 GAS LIFT; 8,797.2 INTERMEDIATE LINER; 2,693.9 -9,318.0 TIE BACK CASING; 26.4- 8,691.4 SEAL ASSY; 8,681.8-8,691.4 GAS LIFT; 3,521.0 SURFACE; 27.3-2,835.0 SHOE; 2,832.5-2,835.0 XO Threads (Casing); 2,713.4- 2,714.8 Liner Top Packer; 2,693.9- 2,713.4 CONDUCTOR; 27.5-107.5 HANGER; 35.5 HANGER; 27.3-28.4 HANGER; 26.4-26.9 KUP INJ 2S-13A ... WELLNAME WELLBORE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Date:Wednesday, April 17, 2024 3:31:42 PM Attachments:image001.png From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, April 17, 2024 12:51 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris- KRU 2S-13A (PTD 216-104) operating under AIO 2C.069 has had the IA circulated out with clean fluids. CPAI intends to bring the well back on gas injection for a 30 day monitor period to investigate the ability for the IA to remain under the DNE of 2400 psi. Depending on the results of the 30 day monitor period the proper paperwork for continued injection or repair will be submitted at that time. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Byrne, Jan Sent: Monday, March 4, 2024 11:39 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris, KRU 2S-13A (PTD 216-104) (AIO 2C.069) exceeded the allowed two non-thermal related IA pressure bleeds per month. The well will be shut in and freeze protected while a path forward is determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Date:Tuesday, March 5, 2024 9:41:32 AM Attachments:AnnComm Surveillance TIO for 2S-13A.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, March 4, 2024 11:39 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2S-13A (PTD 216-104) Report of exceeding allowed pressure bleeds Chris, KRU 2S-13A (PTD 216-104) (AIO 2C.069) exceeded the allowed two non-thermal related IA pressure bleeds per month. The well will be shut in and freeze protected while a path forward is determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 2S-13A 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2S-13 2024-02-23 2160 1380 -780 IA 2S-13 2024-02-26 2280 1050 -1230 IA 2S-13 2024-03-01 2405 1067 -1338 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 1/16/2017 2S-13A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: GLV C/O6/23/2017 2S-13A pproven Casing Strings Casing Description TIE BACK CASING OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 26.4 Set Depth (ftKB) 8,691.4 Set Depth (TVD)… 5,704.8 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd563 Casing Description INTRM LINER OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 8,682.2 Set Depth (ftKB) 10,398.2 Set Depth (TVD)… 6,350.5 Wt/Len (l… 29.70 Grade L80 Top Thread Hyd 563 Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,682.2 5,699.8 56.24 PACKER 7-5/8" X 10-3/4"(2RH) ZXP w/ HD Liner Top Packer 6.760 8,702.1 5,710.8 56.51 HANGER 7-5/8" X 10-3/4" HMC Liner Hanger 6.800 Casing Description A-3 SLOTTED LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 9,968.7 Set Depth (ftKB) 16,829.0 Set Depth (TVD)… 6,251.6 Wt/Len (l… 11.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 9,968.7 6,267.4 71.25 PACKER HRD-E ZXP Liner top packer 5 1/2" x 7 5/8" L-80 5 1/2" Hydril 563 pin 5.750 9,988.66,273.7 71.81 PACKOFF RS packoff Seal Nipple 5 1/2" L-80 5 1/2" Hydril 563 box X box 4.870 9,991.2 6,274.5 71.89 HANGER Flex-Lock Liner hanger 5 1/2" x 7 5/8" L-80 - 5 1/2" Hydril 563 pin X pin 4.830 10,001.0 6,277.5 72.17 SBE Seal Bore Extension 80-40 (4.75" ID) 5 1/2" Hydril 563 box X pin 4.750 10,463.9 6,352.4 89.32 SWELL PACKER 4½" IBTM Swell Packer Baker 6.37" OD 5 SN# 049169-001-24 (A3 @ 10434') 3.950 14,392.36,295.187.81 SWELL PACKER 4½" IBTM Swell Packer Baker 6.37" OD SN# 049169 -001-15( Fault @ 14620') 3.950 Casing Description LEM / ZXP OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 9,985.1 Set Depth (ftKB) 10,285.9 Set Depth (TVD)… 6,341.0 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Casing Description A3 LINER w/ PERF PUPS OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,221.9 Set Depth (ftKB) 16,895.3 Set Depth (TVD)… 6,250.1 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 10,241.8 6,334.7 80.96 NIPPLE Baker 5.5" "RS" Packoff Seal Nipple 14# L-80 Hyd 563 box x box 4.860 10,244.6 6,335.2 81.07 HANGER Baker 5.5" x 7.63" "DG"Flex-Lock Liner hanger L- 80 Hyd 563 pin x pin 4.830 10,265.0 6,338.2 81.92 SBE (Seal Bore Extension) Baker 190-47 Sealbore Extension, 5.5" Hyd 563 pin x 5.5" Hyd 563 box 4.750 10,456.6 6,352.3 89.13 SWELL PACKER Baker -- "Swell Packer #3- "C" 6.38" OD SN: 049169-001-11 3.960 14,578.6 6,300.9 88.11 SWELL PACKER Tam -- "Swell Packer #2- "B" 5.7" OD SN:50151812-01 3.958 14,977.1 6,306.4 90.36 SWELL PACKER Tam-- "Swell Packer #1- "A" 5.75" OD SN: 50151812-02 3.958 Tubing Strings Tubing Description UPPER COMPLETION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 35.6 Set Depth (ft… 10,019.9 Set Depth (TVD) (… 6,283.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-m Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 35.5 35.5 0.02 HANGER Cameron 11" x 4-1/2" Tubing Hanger 3.900 9,918.8 6,250.7 69.84 NIPPLE Camco 3.81” DB nipple w/ (RHC plug body pre-installed ( 69.81 Deg) - PULLED 1-2-2017) 3.813 9,991.5 6,274.6 71.90 LOCATOR Baker 4-1/2" Locator 3.880 9,993.3 6,275.1 71.95 SEAL ASSY Baker 4-1/2" GBH-22 Seal Assy 3.880 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,521.03,010.9Camco KBMG 1 GAS LIFT DMY BK 0.000 0.06/11/2017 2 8,797.2 5,762.4 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/11/2017 Notes: General & Safety End Date Annotation 6/4/2019 NOTE: Waivered for continued WAG injection with known TxIA communication on gas Comment SSSV: NONE MULTIPLE LATERALS - 2S-13A, 6/4/2019 8:20:11 AM Vertical schematic (actual) A3 LINER w/ PERF PUPS; 10,221.9-16,895.3 A-3 SLOTTED LINER; 9,968.7- 16,829.0 INTRM LINER; 8,682.2-10,398.2 LEM / ZXP; 9,985.1-10,285.9 A4 LINER; 10,024.0-16,945.9 SEAL ASSY; 9,993.2 LOCATOR; 9,991.5 NIPPLE; 9,918.8 GAS LIFT; 8,797.2 INTERMEDIATE LINER; 2,693.9 -9,318.0 TIE BACK CASING; 26.4- 8,691.4 GAS LIFT; 3,521.0 SURFACE; 27.3-2,835.0 CONDUCTOR; 27.5-107.5 HANGER; 35.5 KUP INJ KB-Grd (ft) 27.50 Rig Release Date 2/6/2016 Annotation Last WO: End Date 2S-13A H2S (ppm)Date... TD Act Btm (ftKB) 16,905.3 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032072001 Wellbore Status INJ Max Angle & MD Incl (°) 93.12 MD (ftKB) 10,819.52 WELLNAME WELLBORE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-13A KUPARUK RIV UNIT 2S-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-13A 50-103-20720-01-00 216-104-0 W SPT 6271 2161040 1800 2157 2156 2156 2152 580 1990 1975 1965 REQVAR P Brian Bixby 7/2/2022 MITOA as per AIO 2C.069 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-13A Inspection Date: Tubing OA Packer Depth 930 1150 1150 1140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704085331 BBL Pumped:3.8 BBL Returned:3.8 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 9 9 AIO 2C.069MITOA James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 15:41:56 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-13A KUPARUK RIV UNIT 2S-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-13A 50-103-20720-01-00 216-104-0 W SPT 6271 2161040 3800 2152 2155 2155 2156 607 923 921 920 REQVAR P Brian Bixby 7/2/2022 MITIA as per AIO 2C.069 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-13A Inspection Date: Tubing OA Packer Depth 905 4090 3990 3970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704083954 BBL Pumped:5.1 BBL Returned:5.1 Friday, July 22, 2022 Page 1 of 1 MEMORANDUM TO: Jim Regg � l P.1. Supervisor FROM: Adam Earl Petroleum Inspector 7'23A Z-OZa NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2S -13A KUPARUK RIV UNIT 2S -13A Ste: Inspector Reviewed Bye P.I. Supry IT13y% Comm Well Name KUPARUK RIV UNIT 2S -13A API Well Number 50-103-20720-01-00 Insp Num: maAce200705122800 Permit Number: 216-104-0 Rel Insp Num: Inspector Name: Inspection Date: Adam Earl 7/4/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2S -13A Type Inj W TVD 6271 Tubing 2008 - 2008. 2008 - 2008 -_ PTD 2161040 'Type Test SPT Test psi 3600 IA 680 3985 - 3890 - 3880 - BBL Pumped: 52 BBL Returned: 5.2 OA 60 - 580 5805s0 , Interval REQVAR P/F P ✓ Notes: MIT IA tested as per AIO 2C.069 to M.A.I.Pressure Wednesday, July 8, 2020 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor Or FROM: Adam Earl Petroleum Inspector I-e-oz'e) NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2S -13A KUPARUK RIV UNIT 2S -13A Sre: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT 2S -13A API Well Number 50-103-20720-01-00 Inspector Name: Adam Earl Insp Num: mkAGE200705123224 Permit Number: 216-104.0 Inspection Date: 7/4/2020 i Rel Insp Num: I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2s -13A Type Inj w •TVD dn1 Tubing IA 2007 00 2005 2004 2008 ' PTD 2161oao —Type Test SPT fest pSl 800 - 980 - 970 • 970 - -- BBL Pumped: 4.7 -BBL Returned: 55 ' OA 240 1990 1970. 1960 - Interval REQVAR P/F P Notes: MIT OA tested as per AIO 2C.069 Wednesday, July 8, 2020 Page I of I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, April 8, 2019 7:48 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: Report of anomalous annuli pressures 2S -13A (PTD 216-104) Update 4-8-19 Attachments: 2S-13 90 day TIO trend 4.8.19.JPG; MIT KRU 2S -13A diagnostic MITIA 4-8-19.xlsx Chris, This email has a corrected subject header. Please dispose of the email just sent a minute ago, thanks. 2S-13 is coming to the end of the 90 day monitor period and the well exhibited no signs of annular communication while on water injection. The MITIA to MAIP was completed, but the LDL was unable to be completed due to the ultrasonic tool being out of Alaska. The tool is now back in Alaska and CPAI has plans to make a slickline drift run tomorrow and complete the LDL as soon as possible. CPAI would like to extend the monitor period out another 30 days to allow for the logging to be completed and generating the AA application. The well will remain on water injection only throughout this time. A 90 day TIO trend and 10-426 for the MAIP MITIA are attached. Please let us know if you disagree or have any questions with the plan. Regards, Jan Byrne / Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM ConocAPMps From: ell Integrity Supv CPF1 and 2 Sent: Tuesday, JaftaIX101, 2019 5:52 PM To: Wallace, Chris D (DOA)-<eWs.waIlacei Cc: Senden, R. Tyler <R.T Ier.Senden r Subject: RE: Report of anomalous annuli r 2S -13A (PTD 216-104) Update 01-01-19 Chris, The end of the 30 -day monitor period on gas injection on 2S -13A is c to an end today. Unfortunately the results are not positive; the IA has continued to demonstrate a slow unexplained re surization. We obtained passing packoff tests and an MITIA to 3000 psi on December 19th. There was a temperature spike a nd that time so we continued to monitor the well in hopes that the pressure rise would turnout to be thermal, to no avail. CPAI intends to pursue an AA and are planning to WAG the well to water injection so that we ca tain a 30 -day monitor on water injection to ensure that this is a gas -only leak. But we are anticipating submitting an AA to allow gas injection on this well, utilizing maintenance bleeds to control the IA pressure. But before doing so, we will be pursuing an MITIA to the higher maximum anticipated injection pressure and attempting an LDL in hopes of finding a discrete • • 2L, -\ 04k ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SEP 2 6 2017 AOGCC September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNED ,62 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sin ely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate L.f Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend H Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program H Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: _PROD to WAG ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development ❑ Exploratory H 216-104-0 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic ❑ Service H 6.API Number: 99510 50-103-20720-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2S-13A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 16907 feet Plugs measured feet true vertical 6249 feet Junk measured feet Effective Depth measured 16907 feet Packer measured 9985, 10286 feet true vertical 6249 feet true vertical 6272,6341 feet Casing Length Size MD TVD Burst Collapse Conductor 119' 20" 119' 119' Surface 2847' 13-3/8" 2847' 2560' Intermediate#1 5997 10-3/4" 8703' 5711' Intermediate#2 1716 7-5/8" 10410' 6350' A4 Liner LEM 163' 4-1/2" 10036' 6288' RECEIVED A3 Liner LEM 6673' 4-1/2" 16907' 6250' t� Perforation depth Measured depth 10518-14565; feet JUL !� 6 2017 15089-16772AOG h True Vertical depth 6300-6352;-6352; { feet 6252-6304 Tubing(size,grade,measured and true vertical depth) 4 1/2" L-80 10,202 MD 6283.19TVD Packers and SSSV(type,measured and true vertical depth) Baker ZXP Paker:9985'MD(6727'TVD);Baker ZXP Packer: 10286 MD(6342 TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NOVTreatment descriptions including volumes used and final pressure: S ;',.NNE) O i 3 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 949 880 0 1066 285 Subsequent to operation: 0 0 7900 85 2030 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development H Service ❑., Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ H SUSP❑ SPLUG H 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: 317-165 • Authorized Name: Mark Shulman Contact Name: Mark Shulman Authorized Title: Senoirtil Petroleum Engineer Contact Email: Mark.shulmanCOP.com Authorized Signature: IlAV Date: 7/?0'7 Contact Phone: 263-3782 1/i—i- 101q-/i-7-- 9 q7 Form 10-404 Revised 4/2017 ,% l7 RBDMS JUL2 / 201/ i%�'� �O�$l `/ I Submit Original Only • = 2S-13A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/24/2017: (ISW) MIT-IA PASS TO 2800 PSI. (CHUCK SCHEVE) 6/12/2017: Convert to Produced Water Injection. Well brought online KUP 2S-13A - Drilling Conoc©Phillips ' &Welts Well Attribu Max Angla TD Alask<1,1I'i... Wellbore API/OWI Field Name Wellbore Status ncl P) MD(ft(B) Act Btm(ftKB) 0oralco8trittips 501032072001 KUPARUK RIVER UNIT INJ 93.12 10,819.52 16,905.3 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-25-136.7/26/20173:32:15 PM SSSV:NONE Last WO: 27.50 2/6/2016 Vertical schemabe(44-) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Manor;23.6-� , ,. Last Tag: 1/16/2017 Rev Reason GLV C/0 pproven 6/23/2017 EIP - ® Casing Strings ...W.cllk Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.250 27.6 107.6 107.5 78.70 H-40 Casing Description 'OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 133/8 12.415 27.4 2,835.1 2,551.3 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread s�CONDUCTOR;27.5-107.6- INTERMEDIATE LINER 103/4 9.950 2,693.9 9,318.0 6,010.3 45.50 L-80 Hyd 521 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTRM CASING 7 5/8 6.875 26.2 10,434.0 6,351.8 29.70 L80 Hyd 563 3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE,27.3-2,835.0 a TIE BACK CASING 7 5/8 6.875 26.4 8,691.4 5,704.8 29.70 L-80 Hyd563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread GAS LIFT;3.5093 - A-3 SLOTTED LINER 4 1/2 3.958 9,968.7 16,829.0 6,251.6 11.60 L-80 IBTM • Liner Details • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) TIE BACK CASING,26.4- 9,968.7 6,267.4 71.25 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.750 0.6914 r s: 1/2"Hydril 563 pin GAS LIFT;8,7854 9,988.6 6,273.7 71.81 PACKOFF RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.870 INTRM LINER,8,682.2-10,398.2 box X box Ali 'IP 9,991.2 6,274.5 71.89 HANGER Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 112" 4.830 Hydril 563 pin X pin am ma INTERMEDIATE LINER;2,693.9 10,001.0 6,277.5 72.17 SBE Seal Bore Extension 80-40(4.75"ID)5 1/2"Hydril 4.750 -9,318.0 563 box X pin NIPPLE;9,807.0 aa� 10,463.9 6,352.4 89.32 SWELL 4'/a"IBTM Swell Packer Baker 6.37"OD 5 SN# 3.950 PACKER 049169-001-24(A3 @ 10434') LOCATOR;9,979.8 14,392.3 6,295.1 87.81 SWELL 4'/"IBTM Swell Packer Baker 6.37"OD SN# 3.950 PACKER 049169-001-15(Fault @ 14620') SEAL ASSY;9,981.5 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LEM I ZXP 41/2 3.958 9,973.4 10,274.2 6,339.5 12.60 L-80 IBTM 1 sit I Casing Description OD(in) ID hn) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NI A3 LINER w/PERF 4 1/2 3.958 10,221.9 16,895.3 6,250.1 12.60 L-80 IBT-m PUPS liss as Liner Details M. Nominal ID wr Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) I, 10,241.8 6,334.7 80.96 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 14#L-80 4.860 Hyd 563 box x box LEM/ZXP;9,973.4-10,274.2 10,244.6 6,335.2 81.07 HANGER Baker 5.5"x 7.63""DG"Flex-Lock Liner hanger L- 4.830 80 Hyd 563 pin x pin i, 10,265.0 6,3382 81.92 SBE (Seal Baker 190-47 Sealbore Extension,5.5"Hyd 563 pin x 4.750 aa 18Bore 5.5"Hyd 563 box INTRM CASING;8,868.2- IIII Extension) 10,434.0 MI 10,456.6 6,352.3 89.13 Swell Packer Baker-"Swell Packer#3-"C"6.38"OD SN: 3.960 049169-001-11 14,578.6 6,300.9 88.11 Swell Packer Tam-"Swell Packer#2-"B"5.7"OD 3.958 SN:50151812-01 14,977.1 6,306.4 90.36 Swell Packer Tam-"Swell Packer#1-"A"5.75"OD SN: 3.958 "-"' 50151812-02 Tubing Strings I+ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/rt) Grade Top Connection 4.5"IBT-m upper 4 1/2 3.958 23.8 10,008.2 6,279.7 12.60 L-80 IBT-m Inn completion ling Completion Details IsEnl Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) non MUM 23.8 23.8 0.01 Hanger Cameron 11"x 4-1/2"Tubing Hanger 3.900 WOW 9,907.0 6,246.6 69.50 NIPPLE Camco 3.81"DB nipple w/(RHC plug body pre-installed 3.813 1M (69.81 Deg)-PULLED 1-2-2017) imini Mil 9,979.8 6,270.9 71.56 LOCATOR Baker 4-1/2"Locator 3.880 • 9,981.5 6,271.4 71.61 SEAL ASSY Baker 4-1/2"GBH-22 Seal Assy 3.880 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (11KB) Make Model OD(in) Sery Type ype Type (in) (psi) Run Date Com 1 3,509.3 3,004.1 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/11/2017 2 8,785.4 5,756.1 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/11/2017 Notes:General&Safety ermal End Date Annotation imoso 1/16/2017 NOTE: MO Exami -11•10- A-3 SLOTTED LINER;0829 6,829 9,9138.7- A3 LINER w/PERF PUPS; 10,221.9-18,895.31 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Wednesday,June 28,2017 P.1.Supervisor 1 `�j� ?(T I t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2S-13A FROM: Chuck Scheve KUPARUK RIV UNIT 2S-13A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-13A API Well Number 50-103-20720-01-00 Inspector Name: Chuck Scheve Permit Number: 216-104-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625092413 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2S-13A Type Inj W TVD 6271 Tubing 1920 1920 1920 1920 ' PTD 2161040 Type Test SPT ITest psi 1568 IA 260 2800 - 2720 2720 - BBL Pumped: 3.9 BBL Returned: 3.9 OA 600 825 • 825 ' 825 Interval INITAL P/F Notes: Initial MITIA post conversion per Sundry 317-165 SCORE® AUG2 la-017 Wednesday,June 28,2017 Page 1 of 1 VOF Tb • 4 ,, v7,• THE STATE Alaska Oil and Gas =--7-4-1;14 Conservation Commission 333 West Seventh Avenue *R,P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 :5 Fax: 907.276.7542 www.aogcc.alaska.gov Mark Shulman Petroleum Engineer NOV 0 12 01 t, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-13A Permit to Drill Number: 216-104 Sundry Number: 317-165 Dear Mr. Shulman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Cathy P. oerster Chair DATED this )I�of May, 2017. RBDMS Lk, MAY 1 5 2017 • • RECEIVED • STATE OF ALASKA APR 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 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: PROD to WAG ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development 2 - 216-104 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20720-01. 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No E 1 KRU 2S-13A , 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL025603,ADL025590 t I Kuparuk River Field/Kuparuk River 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): 16,907' 6249' - 16907' 6249' 3800 None None Casing Length Size MD TVD Burst Collapse Conductor 119' 20" 119' 119' Surface 2847' 13-3/8" 2847' 2560' Intermediate#1 5997 10-3/4" 8703' 5711' Intermediate#2 1716 7-5/8" 10410' 6350' A4 Liner LEM 163' 4-1/2" 10036' 6288' A3 Liner LEM 6673' 4-1/2" 16907' 6250' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10518-14565,15089-16772 6300-6352,6252-6304 4-1/2" L-80 10,020 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV:NONE;Packer:Baker ZXP;Packer:Baker ZXP SSSV:NONE;Packer:9985 MD(6727 TVD),Packer:10286 MD(6342 TVD) 12.Attachments: Proposal Summary 2 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service E • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/10/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Mark Shulman Contact Name: Mark Shulman Authorized Title: Petroleum Engineer Contact Email: mark.shulman(a�cop.com ,� Contact Phone: (907)263-3782 Authorized Signature: %K� /f+� Date: 11/2--C1/47 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test V Location Clearance ❑ NSF ¶ rip 1, . Other: Post Initial Injection MIT Req'd? Yes trNo ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /t7— 40 ` MAY 1 20171 RBDMS APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S./(_/7 N `[ j� lI/50`^ I�P"'1�/ I I Submit Form and Form 1Q-408 Revised 4/2017 alid for 12 months from the date of approval. Attachments in Duplicate Mark Shulman Petroleum Engineer P.O.Box 100360 Anchorage,AK 99510-0360 ConocoPhillips Phone:(907)263-3782 April 25, 2017 RECEIVED AOGCC Commissioner APR 22017 State of Alaska, Oil & Gas Conservation Commission AOGCC 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 2S-13A from Production service to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-13A (PTD# 216-104). If you have any questions regarding this matter, please contact myself at 263-3782. Sincerely, Mark Shulman Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2S-13A(PTD# 216-104) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 2S-13A was completed as an injector on 12/18/16 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 2S-11, 2S-12 and 2S-14. The top of A-sand was found at 9,557' MD (6,113'TVD) Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers (2S-11, 2S-12 &2S-14), there are no additional production/injection wells located within a 1/4 mile radius of the 2S-13A penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-13A is good and is classified as a "Single Casing"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 10286' and (6341'tvd). A State-witnessed MIT-IA will be performed once well 2S-13A is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (8860' -10260' and/5704' -6338' tvd) to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 20" Conductor was pre-driven The 13-3/8" Surface casing was cemented with 1460 sx lead 11 ppg, 278 sx Tail slurry 12.0 ppg. The 10-3/4" Intermediate casing was cemented with 1535 sx 15.8 ppg Class "G". The 7-5/8" liner top packer 348 sx 15.8 ppg Class"G" • • 2S-13A & AL1 Dual Lat . Grassroots Horizontal A-Sand Injector ConocoPhillips Final Wellbore Schematic D142 RKB Last Edited:SAB-1/12/17 20"Conductor to-117.5' 16"Surface Hole Y€ 4-W IBTM Tbing rirtIll 0121 Surface Casing 13-3/8"68#L-80 HYD 563 2,847.1'MD/2,559.3'TVD c.-J KBGM GLM w/DV 3521.03"MD 3010'ND -- 10-3/4"Planned TOC:5,491.5'(at minimum 12-1/4"X 13-1/2"Intermediate#1 Hole 500'MD above C37) C-37:6,851.5'MD/4,659 5'TVD I 7-5/8'X 10?%"-Liner Top Packer 8;693.97'MD Growler-AA(Iceberg):7,233.5'MD/4,867.5'TVD ' Top Calm:8,217.5'MD/5,443.5'TVD Top Bermuda: 8,371.5'MD/5,529.5'TVD U. KBGM GLM w/DCK-2 SOV 8797.2'MD 5761'TVD Ps 10-W Whipstock/Window 8,845'MD HRZ.9,248'MD/5,978'TVD 10 3/4"INT#1 Liner 10-3/4"45.5#L-80 Hyd521 9,329.5'MD/6,029.5'TVD Lower Kalubik(K-1 Marker):9,700'MD/6,170'TVD \.... ,k ® Lateral Entry Module(LEM),Baker,w/seal.assembly&ZXP \r/S#1 i- packer set @ 9 ' 3-7� riterrm-_ - ` `'-'-` Top Kuparuk C.9,960'MD/6,262'ND -- --- \ LEM Top 10032.6 MD Kuparuk A4:9,980 MD/6,271 TVD LEM Bottom. 10035.6MD • \ \2S-13PB1/25-13/2S 131_1 — 7-5/8"Whipstock Bottom of Window 10,055'MD 13AL4 TO 16,957.72'MD/6,208'TVD 7-5/8"Flex Lock Liner Hanger/ZXP 10,233.7 MD Kuparuk A3:10,162'MD/6,320'ND �_u a s a oQ hV 1.1..e. 2S-13A:A3 Linec16,907.01'MD/6,249'TVD Jntermediate Casinq 7-5/8"29.7#L-80 Hyd563 Casing 10,409.89'MD/ 6-3/4"Production Hol' 6,351'ND(88°) Production liner: 4-W liner w/pre-perforated pups 2S-14 • • 2S-13L1 ADL025590 Southern 1 r 2S-13 Miluveach ! ' Unit ADL390680 1 + � 1 I � r 1 r 1 t i r N "Cr ,I Kuparuk River Unit (F 1' 2S 2S-13PB1 , Iry ADL025603 ADL380051 -Well Trajectory -2S-13AOpen Interval -2S-13AL1 Open Interval II 2S-13A 01 Quarter Mile Radius 2S-13AL1 01 Quarter Mile Radius Wells within Open Interval Radius Active Well - - - Inactive Well jv ConocoPhillips _ _ Alaska,Inc. �_. I AKUnitA •) Well Pad 2S-13A and 2S-13AL1 BRPC Leases 0 0.2 0.4 0.6 Injection Sundry Miles CPAI Leases 3/6/2017 - • • - (a r2 i(= {} \ i� /\\ \\\ /\{ 2! E!, ; 2 fltA 2 }(\ }{- /}} 2& ~ kf}7 \ ,,g P.-5 \{©© /{-` \ o; \ \� 2. 2 � \\ \1 ~ * ; 41 ii } \ E , U ƒ! ® ti ti _ \\ / - \ \k \ ( ( \ \\ L 6 j \\ 6 og ( f. 41 2 /. 4,, 4, § ; ] j j ) | \ \ j \ • • o 9 0 N C 1 k O 1 ` ' , N o z I \S\� C . r. 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' !r- r- N- N- n Q.r a :d W J 0 iN 0000 N N N N m y 7 E co cu0 S co co co co M N Z 6j LL a I� a m C.) O it E rn co vi 6W Oz ac Co m a 1 V °cJo m EJE Z ` vw 0) Co Cl) o J a c I ..J O. E a r ° O co 20 - �ON a � 1 N O II, l " Y !I, el V et V U .�^` ` Z C wo Q e } O E o r O Oth N @ (� N c0 0.O H0 ! N p Z N R C6 C A, '.. c ' . Q N f0 CO to c c0 ~ E 1 w Cl) m N ltwC C - N a► f:1 sl d cre O Y 0 a HI O m U co CZ Z U I !I RS CO w6 C66 w N CO CO d co in O O O O 0 C < N N CNO ,c6. •co. ,.Co Co Co I C Z CO CO 5 � ma, al E 001ThL w 037 ~ coo coo coo coo coo ano•- '0 3 N N N N N N N N a d Ca O V c ami C7) N Z !, H c c Z c N O M U p c� N Q o O Q o 0 « •C C U U U U U U U p m J a) .2- d - U 0 0 a 3 _° d a m ti E a 0 !o 0 O' LL E 2 ° 0 E p d E E a w w w w W J 3 F. o a 0 0 o w ° 0 0 RECEIVED • STATE OF ALASKA • JAN 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A && 1a.Well Status: Oil 0 . Gasp SPLUG El Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0- Exploratory❑ GINJ ❑ WINJ El WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 12/18/2016 216-104/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 11/9/2016 , 50-103-20720-01-00 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3099.9'FNL, 1672.2'FEL,Sec 17,T1ON, R8E, UM 11/20/2016 KRU 2S-13A • Top of Productive Interval: 9.Ref Elevations: KB:159.1 17. Field/Pool(s): 3235'FNL,2317'FEL,Sec 18,T1ON, R8E, UM GL:120 BF: Kuparuk River Field/Kuparuk Oil Pool - Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 2013'FNL,710'FEL,Sec 7,T1ON, R8E, UM N/A ADL 25603,ADL 25590 " 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 480898 y-€ 31.51i2'19Sa Zone-4 16917/6250 ALK 2677,ALK 2678,ALK 2675 TPI: x- 474974 y- 5929831 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 476578 y- 5936327 Zone-4 N/A 1436/1412 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I 8847/5789 • 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 78.7 H-40 39.5 145.5 39.5 145.5 42 Pre-installed&cemented 13 3/8 68 L-80 39.5 28477 39.5 2559 16 1460 sx LiteCrete 11 ppg,278 sx 12 ooa 10 3/4 45.5 L-80 2705 9329.5 2512 6029.5 12.25x13.5 1535 sx 15.8 ppg Class G 7 5/8 29.7 L-80 38 10410 38 6351 9.875 97.6 bbls 15.8 Class G 41/2 11.6 L.80 10233.7 16907 6333 6249 6.75 Liner 24.Open to production or injection? Yes 0 No El 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4 1/2 10234 10234/6333 Perforated Pups @ 10518-16907 MD and 6352-6249 TVD 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. 'W Was hydraulic fracturing used during completion? Yes❑ No 0 Z' �I l� Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L V 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 1/8/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/17/17 8 hrs. Test Period 490.43 263 0.23 664 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 288.71psi 1035 24-Hour Rate 1381 917 1 Form 10-407 Revised 1/V0 1/71- -1/2q/17-.‘CONTINUED ON PAGE 2 RBDMS l - FEB - 2 2017 Submit ORIGINIAL on • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, FromlTo),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1436 1412 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 10162 6320 information, including reports,per 20 AAC 25.071. West Sok Sand 1918 1836 West Sk Base 2766 2503 C-80 3309 2879 C-37 6840 4655 Top HRZ 9248 5979 Top Kalubik 9490 6086 Kuparuk C 9949 6260 Kuparuk A5 9981 6271 Kuparuk A4 9985 6272 Kuparuk A3 10162 6320 TD(A3) 16917 6250 Formation at total depth: Kuparuk A3 31. List of Attachments: Daily Operations Summary,Definitive Survey,Cement Report,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick al 263-4249, Email: Scott.A.Brunswickacop.com t, Printed Name: G.L.Alvord / Title: Alaska Drilling Manager / Signature: hl L...+ O .& Phone: 265-6120 Date: (LAI2�i'Z INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • 0 2S-13A & A L1 Dual Lat Grassroots Horizontal A-Sand Injector ConocoPhilli s Final Wellbore Schematic D142 RKB p i 10. r, Last Edited:SAB-1/12/17 fir 444 20"Conductor to-117.5' 16"Surface Hole 2 arkiil ,`,,'1,)1,,,,,b 4-W IBTM Tbing git 113Surface Casino 13-3/8"68#L-80 HYD 563 2,847.1'MD/2,559.3'TVD ii4 4, of KBGM GLM w/DV 3521 03"MD 3010'TVD 10-3/4"Planned TOC:5,491.5(at minimum 12-1/4"X 13-1/2" Intermediate#1 Hole 500'MD above C37( �°/ C•37:6,851.5'�MD 14,659:5'ND :::;' (®�=I '7-5/8"x10-'/."Liner To.Packer 669397'MD __ Growler-AA(Iceberg):7,233.5'MD/4,867.5'TVD S ":',....iTop;Cairn 8,217.5'MD/5,443.5'TVD " �I Top Bermuda 6,371.5'MD/5,529.5.TVD i il 1. 4'4dr.Z.,, ::"„ L , ,d � KBGM GLM w/DCK-2 SOV 8797.2'MD 5761'ND ' 10-% Whipsto ndow 8,845 MD HRZ 9248 MD/5978 ND Ig} � � '� /�%„ 10 3/4 Linar • � �; 10-314"45.5#t-80 Hyd521 9,329.5'MD/6,029.5'TVD ' - F. weal `"; Low blk(K-1 ker).9,7 / , 0 TV �a f '. r Katu ar 6 17 D ' til Entry w. { l)$akaMl i!S Tbly$. ''''',4',":,":".,"""::2,6,,,;,',„,,,,,,,,,,16....,.......i.:.!. ;;” � i ,',N4';'-'$'6'-'::,0„o .1J - I ; ' '''''°'kersafe :'''''''2' A; ° - .`YF li, PASop Kuparuk C:9,960 MD/6,262'ND LEM Top: 10032.6'MD ` - _Kuparuk A4-9,980MD 16;271 LEM Bottom. 10035.8'MD gii 2S-13PB1/2S-13/25 13L1 1. — /l II 75/8"Whipstock Bottom oI Window 10,055';MD : 13AL A4?TD!16,957.72'MD/6,208''ND'. ' ``1, 7.:'/;3"Flex Lock Liner Han.er/ZXP 10 233 7 MD Kupandt:A3:10,162'MO/6,320'ND • ."Orange P r,. il ".;.$1.Zi 4 gt iii ______u_viii________- 28-13A,A3 Liner,16 907 01'MD/6'249'TVD intermediate Casing 7-5/8"29.7#L-80 Hyd563 Casing 10,409.89'MD/ 6-3/4"Production Hole 6,351'ND(88°) Production liner: 4-'/:"liner w/pre-perforated pups 0' !perations Summary (with Timelog Depths) ..t 2S-13 Coinoccehillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/28/2016 10/28/2016 3.00 MIRU MOVE MOB X Move pipe shed,motor module,pump 0.0 0.0 00:00 03:00 module,pit module,and rock washer and stage at end of location. 10/28/2016 10/28/2016 2.50 MIRU MOVE RURD X Install tongue on sub,skid rig floor, 0.0 0.0 03:00 05:30 and raise stompers.SIMOPS Spot rig mats for moving sub to 2S-13 10/28/2016 10/28/2016 3.00 MIRU MOVE RURD X Continue spotting mats for moving sub 0.0 0.0 05:30 08:30 to 2S-13.SIMOPS Change out plumbing for steam lines throughout rig 10/28/2016 10/28/2016 3.75 MIRU MOVE MOB X Move sub off 2S-09 and spot over 2S- 0.0 0.0 08:30 12:15 13. 10/28/2016 10/28/2016 1.00 MIRU MOVE MOB X Set sub stompers. 0.0 0.0 12:15 13:15 10/28/2016 10/28/2016 0.75 MIRU MOVE RURD X Skid rig floor into drilling position. 0.0 0.0 13:15 14:00 10/28/2016 10/28/2016 2.00 MIRU MOVE MOB X Spot pit module.SIMOPS Remove 0.0 0.0 14:00 16:00 tongue from sub. 10/28/2016 10/28/2016 0.50 MIRU MOVE MOB X Spot pump module. 0.0 0.0 16:00 16:30 10/28/2016 10/28/2016 0.75 MIRU MOVE MOB X Spot motor complex 0.0 0.0 16:30 17:15 10/28/2016 10/28/2016 1.75 MIRU MOVE MOB X Spot rockwasher and pipeshed. 0.0 0.0 17:15 19:00 10/28/2016 10/28/2016 2.50 MIRU MOVE MOB X Lay herculite and spot cuttings tank. 0.0 0.0 19:00 21:30 Install hand-i-berm around cuttings tank and cellar area.Start heating rig with steam. 10/28/2016 10/29/2016 2.50 MIRU MOVE RURD X Rig up interconnect lines between 0.0 0.0 21:30 00:00 modules and sub.Install plugs in pumps.Position pipe skate rail. Rig accept at 24:00 hrs. 10/29/2016 10/29/2016 2.50 MIRU WELCTL RURD X Open IA to atmosphere and monitor 0.0 0.0 00:00 02:30 for flow-observe small amount of air coming out at first decreasing to static. SIMOPS finish rigging up and take on 12.2 ppg mud to pits.Mobilize lubricator to cellar.Obtain measurements for elevation:RKB to upper LDS 35.55'.RKB to lower LDS 36.46'. 10/29/2016 10/29/2016 - 1.00 MIRU WELCTL MPSP X R/U lubricator and pressure test to 0.0 0.0 02:30 03:30 2000 psi.Pull H-type BPV and observe 950 psi on tubing,0 psi on IA. R/D lubricator. Note:Prior to rigging up lubricator, cycled master/swab valve 3 x times on tree and observed pressure bleeding off through tree cap each time. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X R/U 1/2"line off wing valve to bleed 0.0 0.0 03:30 06:00 trailer and bleed air from tubing,initial pressure of 950 psi decreasing to 250 psi.IA at 0 psi. SIMOPS Rig up to pump IA. Page 1/55 Report Printed: 12/28/2016 111 0 1 •erations Summary (with Timelog ftths) ,�t 2S-13 Coroa:Thitliips LxAa Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1 10/29/2016 10/29/2016 1.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 06:00 07:30 pressure buildup.Observed pressure remain at 250 psi for initial 25 minutes, and then slowly build up to 310 psi. IA at 0 psi with slight vacuum. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 07:30 08:00 initial pressure of 310 psi decreasing to 150 psi.IA at 0 psi. 10/29/2016 10/29/2016 1.75 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 08:00 09:45 pressure buildup.Observed pressure slowly build up from 150 psi to 190 psi.IA at 0 psi. 10/29/2016 10/29/2016 0.25 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 09:45 10:00 initial pressure of 190 psi decreasing to 100 psi.IA at 0 psi. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 10:00 12:30 pressure buildup.Observed pressure slowly build up from 100 psi to 147 psi.IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 12:30 13:00 initial pressure of 147 psi decreasing to 20 psi.IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 13:00 13:30 pressure buildup.Observed pressure slowly build up from 20 psi to 35 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0A 13:30 14:00 initial pressure of 35 psi decreasing to 0 psi.IA at 0 psi. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 14:00 16:30 pressure buildup.Observed pressure slowly build up from 0 psi to 36 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 16:30 17:00 initial pressure of 36 psi decreasing to 0 psi. IA at 0 psi. 10/29/2016 10/29/2016 2.00 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 17:00 19:00 pressure buildup.Observed pressure slowly build up from 0 psi to 25 psi. IA at 0 psi.SIMOPS Rig up hardline to 400 bbl kill tank to circulate KWF. 10/29/2016 10/29/2016 0.25 MIRU WELCTL SFTY X Hold PJSM for killing well with 0.0 0.0 19:00 19:15 12.2ppg KWF,taking returns to kill tank. Page 2/55 Report Printed: 12/28/2016 • 0 Operations Summary (with Timelog titths) 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/29/2016 10/29/2016 1.75 MIRU WELCTL KLWL X Line up and flood lines from rig to kill 0.0 0.0 19:15 21:00 tank.Pressure test to 2000 psi and confirm no leaks-good test. Line up to pump down IA,taking returns through tubing to kill tank.Stage up to 2 bpm and pump 44 bbls of 12.2 ppg • KWF before seeing returns at kill tank, initial pressure of 45 psi increasing to I 236 psi.Continue pumping 168 bbls of 12.2ppg KWF,staging up to 3 bpm, 470 psi.Observe initial returns containing large amount of air and mud weight out fluctuate between 11.7 -12.0+for first 130 bbls pumped and then steadily increase to 12.2 ppg in/out.Shut in well and blow down lines to kill tank. Total volume pumped 212 bbls.Final volume in kill tank 136 bbls.Total losses downhole 76 bbls 10/29/2016 10/29/2016 0.75 MIRU WELCTL OWFF X Monitor for pressure buildup on tubing 0.0 0.0 21:00 21:45 and IA-well static at 0 psi on tubing and 0 psi on IA.Open up tubing and IA to atmosphere and observe both on a vacuum. 10/29/2016 10/29/2016 1.25 MIRU WHDBOP MPSP X Rig up lubricator and test to 2000 psi- 0.0 0.0 21:45 23:00 good test.Install HP-type BPV.R/D lubricator. 10/29/2016 10/30/2016 1.00 MIRU WHDBOP MPSP X Fill tree with water and line up to pump 0.0 0.0 23:00 00:00 down IA to pressure test BPV in direction of flow,monitoring for leaks past BPV through the wing valve. Stage up to 2 bpm and pump 15 bbls 12.2ppg KWF before seeing any pressure increase.Continue pumping total of 24 bbls at 2 bpm,initial pressure of 45 psi increase to 700 psi and level out.Shut in well and observe IA pressure fall to 100 psi.Remove tree cap and open swab valve.Pump down IA at 2 bpm,620 psi for total of 10 bbls,monitoring for any leaks past BPV-no leaks observed.Shut in and blow down lines. 10/30/2016 10/30/2016 1.00 MIRU WHDBOP OTHR X Blow down lines and clean up cellar 0.0 0.0 00:00 01:00 area. 10/30/2016 10/30/2016 2.50 MIRU WHDBOP NUND X Nipple down production tree.Make up 0.0 0.0 01:00 03:30 4-1/2"IBT to top of hanger and confirm it will swallow BPV.Convert HP-type BPV into 2-way check. 10/30/2016 10/30/2016 4.50 MIRU WHDBOP NUND X Nipple up BOPE and dutch riser ring. 0.0 0.0 03:30 08:00 Note:MPD RCD head will not be rigged up until after 7-5/8"casing is cut/pulled to surface. 10/30/2016 10/30/2016 1.00 MIRU WHDBOP RURD X Make up 4-1/2"test joint and rig up to 0.0 0.0 08:00 09:00 test BOPE. Page 3/55 Report Printed: 12/28/2016 4 • • Operations Summary (with Timelog Depths) t 2S-13 ConocoPhiilips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2016 10/30/2016 6.50 MIRU WHDBOP BOPE X Perform shell test.Test witnessed by 0.0 0.0 09:00 15:30 AOGCC Rep.Matt Herrera and Guy Cook.Tested BOPE with 4-1/2"test joint.250/3500 psi,charted for 5 minutes each. Test#1 with 4-1/2"test joint,testing Annular,CV#1,#12,#13,#14,4"kill line valve on mud manifold,and 4"Dart valve. Test#2-Upper 3-1/2"x 6"VBR's,CV #9,#11,mezzanine kill valve,and 4" FOSV Test#3-CV#5,#8,#10,and HCR Kill. Test#4-CV#4,#6,#7. Test#5-Super choke to 1500 psi Test#6-Manual choke to 1500 psi Test#7-CV#2,#5,and manual kill Test#8-HCR choke. Test#9-Upper IBOP Test#10-Manual choke,lower IBOP Test#11 -Lower 3-1/2"x 6"VBR's Test#12-Blind rams,CV#3. Perform Koomey draw down test. Observed initial system pressure at ACC-3040 PSI,MAN-1500 PSI,and annular-1425 PSI.After Closure observed ACC-1900 PSI,200 PSI increase in 15 seconds with 1 x electric motor,and full pressures at 85 seconds w/1 x electric motor and 2 x air pumps.Perform CPAI performance test,function 2 x rams and 1 x HCR and observe 2 x electric pumps attain full system pressure in 20 sec and 2 x air pumps attain full system pressure in 72 sec. Observed 6 nitrogen bottles with an average PSI of 2608 PSI. Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level.Tested primary and remote BOP controls.Note that the upper IBOP failed initial test- aftern functioning and greasing,it re- tested good. 10/30/2016 10/30/2016 0.25 MIRU WHDBOP RURD X Rig down test equipment and blow 0.0 0.0 15:30 15:45 down lines. 10/30/2016 10/30/2016 0.50 MIRU WHDBOP 'OTHR X Service top drive. 0.0 0.0 15:45 16:15 10/30/2016 10/30/2016 3.00 MIRU WHDBOP -MPSP X Remove 2-way check adapter from 0.0 0.0 16:15 19:15 HP-type BPV and attempt to pull BPV. Drain stack to assist with stabbing BPV.Pull with dry rod and observe tubing on a vacuum.Fill hole,observe returns after 40 bbls pumped. 10/30/2016 10/30/2016 1.00 SLOT RPCOMP SLKL X Rig up dutch riser.Fill pipe every 30 0.0 0.0 19:15 20:15 minutes to ensure fluid to surface. 10/30/2016 10/30/2016 2.50 SLOT RPCOMP SLKL X Rig up to run slickline.Fill pipe every 0.0 0.0 20:15 22:45 30 minutes to ensure fluid to surface. Page 4/55 Report Printed: 12/28/2016 r� Operations Summary (with Timelog Depths) t} 2S-13 ConocaPhillips d,xAa Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2016 10/30/2016 0.25 SLOT RPCOMP SLKL X Pressure test slickline lubricator and 0.0 0.0 22:45 23:00 dutch riser to 500 psi-good test. 10/30/2016 10/31/2016 1.00 SLOT RPCOMP SLKL XT Run in hole w/"F"type collar catcher 0.0 0.0 23:00 00:00 and tag up on top of tubing hanger. Work twice,unable to get through.Pull to surface and re-pin catcher with stronger brass.Run in hole and make 15 x attempts to run through tubing- unsuccessful.Pull to surface and inspect tool-observe pin sheared on catcher tool and the wires were bent. SIMOPS-Mobilize 4-1/2"slip-stop catcher with bullnose on bottom from 1-Y pad Note:Total losses since pulling BPV= 88 bbls.Loss rate has slowed to—8 bbl/hr. 10/31/2016 10/31/2016 1.00 SLOT RPCOMP SLKL XT Re-pin F-style collar catcher and work 0.0 0.0 00:00 01:00 through tubing hanger to 40'prior to making up lubricator.Make up lubricator and run in hole to 530'- unable to work tool any further.Pull OOH and inspect tool-observe wires bent. Continue topping off fluid in well, observe loss rate decrease to—6 bbl/hr SIMOPS-Mobilize 4-1/2"slip-stop catcher with bullnose on bottom from 1-Y pad 10/31/2016 10/31/2016 4.00 SLOT RPCOMP SLKL X RIH w/slip-stop catcher tool with 0.0 0.0 01:00 05:00 bullnose and set catcher below GLM. POOH and lay out running tool.RIH w/dummy valve and seat in GLM at 3479'.POOH and lay out running tool. Pressure test IA to 1000 psi to confirm valve seated ok-good test,no sign of return flow through tubing.RIH w/ catcher pulling tool,retrieve catcher, and POOH.Continue topping off fluid in well,observe loss rate of—6 bbl/hr. 10/31/2016 10/31/2016 1.50 SLOT RPCOMP SLKL X Rig down slickline,laying out 0.0 0.0 05:00 06:30 lubricator and dutch riser. 10/31/2016 10/31/2016 1.00 SLOT RPCOMP PRTS X Rig up to pump down IA and pressure 0.0 0.0 06:30 07:30 test packer to 2000 psi,15 min-good test.Rig down lines and blow down. SIMOPS Rig up casing tongs for pulling kill string. 10/31/2016 10/31/2016 3.00 SLOT RPCOMP PULL X Make up landing joint to hanger and 9,814.0 9,772.0 07:30 10:30 monitor IA pressure-0 psi.Back out LDS and pull hanger/release packer. Observe packer release at 210k hookload.PUW 127k.Lay down hanger,remove bail extensions,and change out elevators. Page 5/55 Report Printed: 12/28/2016 • Operations Summary (with Timelog telpths) tat 2S-13 ConacoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/31/2016 10/31/2016 1.50 SLOT RPCOMP CIRC X Shut in tubing and line up to pump 9,772.0 9,772.0 10:30 12:00 down IA.Bullhead 187 bbls 12.2ppg KWF down IA,staging up to 4.5 bpm, 828 psi. 10/31/2016 10/31/2016 4.50 SLOT RPCOMP CIRC X Line up to circulate down tubing and 9,772.0 9,772.0 12:00 16:30 circulate/condition mud for 4 x BU, staging up from 4 bpm,547 psi,5% F/0 to 5 bpm,600 psi,8%F/O. Observe 620 units gas on first bottoms up.Initial MW 12.2 in/12.1 out.After 1.5 BU,observe MW 12.1 in/11.9 out.Final MW 12.2 in/out. Losses while circulating=63 bbls. 10/31/2016 10/31/2016 0.75 SLOT RPCOMP OWFF X Monitor well for flow-observe fluid 9,772.0 9,772.0 16:30 17:15 level drop 2 ft in 30 minutes. 10/31/2016 10/31/2016 0.50 SLOT RPCOMP PULL X Lay down top 4-1/2"IBTm single and 9,772.0 9,745.0 17:15 17:45 blow down kill line and top drive. 10/31/2016 10/31/2016 0.75 SLOT RPCOMP PULL XT Line up hole fill on trip tank,pull 1 x 9,745.0 9,745.0 17:45 18:30 stand 4-1/2"tubing(85 ft long),and attempt to rack back in derrick on raised wooden platform-unable to rack back.Decision made to lay out 4- 1/2"sidways. 10/31/2016 11/1/2016 5.50 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2"IBTm 9,745.0 7,696.0 18:30 00:00 kill string f/9745'-7696',PUW 115k, SOW 86k.Observe 1-2 bbl/hr loss rate. Note:Attempt to monitor hole fill on trip tank,but mud continued to aerate badly and was not filling hole correctly. Swap to pit#5 while troubleshooting issue. Total losses for 24 hr=123 bbls(not including the 187 bbls bullheaded away) OA pressure=260 psi 11/1/2016 11/1/2016 6.00 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2"IBTm 7,696.0 3,250.0 00:00 06:00 kill string f/7696'-3250',PUW 74k, SOW 60k.Observe-1.5 bbl/hr loss rate.Monitor displacement on pit#5. Note:Attempted to swap over to trip tank after investigation but observe similar issue with trip tank pump not able to keep up with hole fill.Rig will inspect pump. 11/1/2016 11/1/2016 5.00 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2"IBTm 3,250.0 115.0 06:00 11:00 kill string f/3250'-115'.Observe-1 bbl/hr loss rate.Monitor displacement on pit#5. 11/1/2016 11/1/2016 0.50 SLOT RPCOMP PULL X Pull OOH and lay down Baker 115.0 0.0 11:00 11:30 retrievable packer,3-1/2"tubing,D- Nipple,and WLEG. 11/1/2016 11/1/2016 0.75 SLOT RPCOMP RURD X Clean and clear rig floor. 0.0 0.0 11:30 12:15 11/1/2016 11/1/2016 0.50 SLOT PLUG BOPE T Install test plug and R/U to test BOPE. 0.0 0.0 12:15 12:45 Page 6/55 Report Printed: 12/28/2016 o Operations Summary (with Timelog Depths) z. 2S-13 Conor01illips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/1/2016 11/1/2016 1.75 SLOT PLUG BOPE T Test BOP upper and lower VBR's and 0.0 0.0 12:45 14:30 the annular with 3-1/2"test joint. 250/3500 psi,charted for 5 minutes each. 11/1/2016 11/1/2016 0.75 SLOT PLUG BOPE T R/D test equipment and install 12.5" 0.0 0.0 14:30 15:15 ID wearbushing. 11/1/2016 11/1/2016 0.75 SLOT PLUG RURD T Rig up to run 3-1/2"tubing. 0.0 0.0 15:15 16:00 11/1/2016 11/1/2016 1.00 SLOT PLUG SFTY T Hold 3rd Quarter HSE/Performance 0.0 0.0 16:00 17:00 Review with all crews and management. 11/1/2016 11/1/2016 1.50 SLOT PLUG PULD T Hold PJSM for running retainer.Make 0.0 229.0 17:00 18:30 up cement retainer and RIH w/7 x joints 3-1/2"EUE cement stinger to 229'. 11/1/2016 11/1/2016 4.25 SLOT PLUG TRIP T RIH w/4"DP stands from derrick f/ 229.0 6,389.0 18:30 22:45 229'-6389',PUW 119k,SOW 87k, run speed 75-90 ft/min,monitoring displacement on pit#5.Observe-1.5 bbl/hr loss rate. 11/1/2016 11/2/2016 1.25 SLOT PLUG PULD T RIH w/4"DP singles from pipe shed f/ 6,389.0 7,272.0 22:45 00:00 6389'-7272',PUW 128k,SOW 90k, run speed 75 ft/min,monitoring displacement on pit#5.Observe-1 bbl/hr loss rate. Total losses for 24 hr=25.5 bbl OA pressure=220 psi 11/2/2016 11/2/2016 3.75 SLOT PLUG PULD T RIH w/4"DP singles from pipe shed f/ 7,272.0 9,811.0 00:00 03:45 7272'-9811',PUW 167k,SOW 100k, run speed 75 ft/min,monitoring displacement on pit#5.Total losses for trip in hole=19 bbls 11/2/2016 11/2/2016 0.50 SLOT PLUG MPSP T Set cement retainer with top at 9811' 9,811.0 9,795.0 03:45 04:15 MD as per Baker and release from retainer,PUW 167k,SOW 100k. 11/2/2016 11/2/2016 0.25 SLOT PLUG RURD T Rig up cement hose and test 9,795.0 9,795.0 04:15 04:30 equipment. 11/2/2016 11/2/2016 1.00 SLOT PLUG MPSP T Line up to pump down DP and IA. 9,795.0 9,795.0 04:30 05:30 Pressure test cement retainer from above.Although lines were flooded beforehand,took 2.5 bbls pumped before seeing any increase in pressure.Pressured up to 3625 psi, shut in and observed pressure drop from 3575 psi to 3430 psi over 15 minutes. Bumped up pressure to 3650psi,shut in,and observed pressure hold at 3580 psi for 10 min. 11/2/2016 11/2/2016 0.25 SLOT PLUG SQEZ T Sting into retainer and perform 9,795.0 9,811.0 05:30 05:45 injectivity test,staging up to 3bpm and monitoring annulus for returns-static. 1.5 bpm @ 890 psi 2.0 bpm @ 900 psi 2.5 bpm @ 980 psi 3.0 bpm @ 1085 psi 11/2/2016 11/2/2016 0.25 SLOT PLUG SFTY T Sting out of retainer and hold PJSM 9,811.0 9,806.0 05:45 06:00 for cement job. Page 7/55 Report Printed: 12/28/2016 Summary (with TimelogDepths) ►� Operations 2S-13 ConocoPhilllips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2016 11/2/2016 0.75 SLOT PLUG RURD T Line up SLB to cement line,batch mix 9,806.0 9,806.0 06:00 06:45 mudpush and cement,line up to take returns through rig choke,and fill choke lines/gas buster. 11/2/2016 11/2/2016 0.75 SLOT PLUG CMNT T SLB pump 2 bbls 12.5 ppg mudpush. 9,806.0 9,806.0 06:45 07:30 Shut in and pressure test cement lines to 4000 psi-good test.Continue pumping 8 bbls 12.5 ppg mudpush at 2.5 bpm, 1308 psi,21.7 bbls 15.8ppg cement at 2.8 bpm,1217 psi,and 3.1 bbls 12.5 ppg mudpush at 2.2 bpm, 994 psi.Clear lines to rig floor with 1.5 bbls water.Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi.Hold 800 psi backpressure with rig choke throughout job. 11/2/2016 11/2/2016 0.50 SLOT PLUG SQEZ T Strip down and sting into retainer. 9,806.0 9,811.0 07:30 08:00 Bleed off IA pressure and open annular-monitor for leaks throughout job.Pump 27.8 bbls WI rig at 3 bpm, ICP 955 psi,FCP 1177 psi,squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer. 11/2/2016 11/2/2016 0.50 SLOT PLUG TRIP T Sting out of retainer,lay out single, 9,811.0 9,609.0 08:00 08:30 and POOH 2 x stands at 1000 ft/hr to 9609'. Note:4.9 bbls of 15.8ppg cement left in hole above retainer.Estimated TOC @ 9704'. 11/2/2016 11/2/2016 1.00 SLOT PLUG CIRC T Drop wiper ball and circulate 2 x BU at 9,609.0 9,609.0 08:30 09:30 12 bpm,2607 psi 11/2/2016 11/2/2016 4.50 SLOT PLUG PRTS T Rig up to pressure test down DP and 9,609.0 9,609.0 09:30 14:00 IA,close annular. Pressure test top of cement retainer/casing/cement to 3500 psi/30 min-unable to obtain good test.Observe pressure bleeding off at 7 psi/min.Troubleshoot surface equipment and try various lineups- still unable to obtain good test. Note:Observe OA pressure at 1000 psi. 11/2/2016 11/2/2016 1.00 SLOT PLUG CIRC T Circulate 1 x BU at 6 bpm,996 psi, 9,609.0 9,609.0 14:00 15:00 10%F/O,MW in 12.2ppg,MW out 12.1 ppg. Note:Started seeing small amount of diesel in returns at surface right after kicking on the pumps.OA pressure decrease to 810 psi. 11/2/2016 11/2/2016 • 1.00 SLOT PLUG PRTS T Line up and attempt to pressure test 9,609.0 9,609.0 15:00 16:00 retainer/casing/cement to 3500 psi for 30 min-unable to obtain good test. Observe OA pressure increase from 810 psi to 1100 psi. 11/2/2016 11/2/2016 0.75 SLOT PLUG OWFF T Monitor well for flow-observe slight 9,609.0 9,609.0 16:00 16:45 flow with small amounts of diesel in mud.Flow out at 85 sec for vis cup. Page 8/55 Report Printed: 12/28/2016 • O., Operations Summary (with Timelog fitths) 2S-13 cotva iliips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2016 11/2/2016 0.75 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 16:45 17:30 Observe flow out slowly increase to 52 sec for vis cup and OA pressure decrease to 620 psi. 11/2/2016 11/2/2016 1.00 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 17:30 18:30 Observe flow out slowly decrease to 65 sec for vis cup and OA pressure decrease to 380 psi. I 11/2/2016 11/2/2016 0.50 SLOT PLUG OWFF T Continue monitoring well for flow.Line 9,609.0 9,609.0 18:30 19:00 up to bleed off OA pressure to kill tank.Bleed off to 270 psi and observe flow out decrease to 105 sec for vis cup.OA pressure fall to 250 psi.Bleed down to 200 psi and observe flow out decrease to 303 sec for vis cup.OA pressure fall to 190 psi.Bleed off to 100 psi and observe pressure climb to 150 psi within 5 minutes and flow our increased to 190 sec for vis cup. 11/2/2016 11/2/2016 2.00 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 19:00 21:00 Observe flow out continue to decrease to static. Leave OA shut in and monitor pressure,fall from 150 to 130 psi. 11/2/2016 11/3/2016 3.00 SLOT PLUG TRIP T Pull OOH and rack back 4"DP f/9609' 9,609.0 6,863.0 21:00 00:00 -6863',monitoring displacement on trip tank. OA pressure=Decrease from 143 psi to 120 psi. 11/3/2016 11/3/2016 3.00 SLOT 'PLUG TRIP T Pull OOH and rack back 4"DP f/6863' 6,863.0 229.0 00:00 03:00 -229',monitoring displacement on pit #5.SIMOPS troubleshoot trip tank pump. OA pressure continue to decrease from 120 psi to 110 psi. 11/3/2016 11/3/2016 1.00 SLOT PLUG PULD T L/D 7 xjoints 3-1/2"EUE and retainer 229.0 0.0 03:00 04:00 running tool. 11/3/2016 11/3/2016 2.00 SLOT PLUG TRIP T P/U Baker test packer and RIH on 4" 0.0 2,760.0 04:00 06:00 DP stands from derrick to 2760', monitoring displacement on pit#5. 11/3/2016 11/3/2016 0.25 SLOT PLUG MPSP T Set test packer and rig up test 2,760.0 2,760.0 06:00 06:15 equipment. 11/3/2016 11/3/2016 1.00 SLOT PLUG PRTS T Line up and pressure test down DP 2,760.0 2,760.0 06:15 07:15 against cement retainer/casing/ cement plug from 2760'downward to 3500 psi/30 min-good test. 11/3/2016 11/3/2016 0.75 SLOT PLUG PRTS T Line up and attempt to pressure test 2,760.0 2,760.0 07:15 08:00 IA(from 2760'to surface)to 3500 psi/ 30 min-unable to get a good test, observe 200 psi drop over 30 min. 11/3/2016 11/3/2016 0.50 SLOT PLUG MPSP T Rig down test equipment and release 2,760.0 2,760.0 08:00 08:30 test packer. 11/3/2016 11/3/2016 0.25 SLOT PLUG OWFF 'T Monitor well for flow-well static. 2,760.0 2,760.0 08:30 08:45 11/3/2016 11/3/2016 1.50 SLOT PLUG TRIP T Pull OOH f/2760'to surface,racking 2,760.0 0.0 08:45 10:15 back 4"DP in derrick and laying out Baker test packer,monitoring displacement on pit#5 Page 9/55 Report Printed: 12/28/2016 Iterations Summary (with Timeloglpths) 1111 0 Y4 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2016 11/3/2016 0.75 SLOT PLUG RURD T Clean/clear rig floor. 0.0 0.0 10:15 11:00 11/3/2016 11/3/2016 0.50 SLOT PLUG SVRG T Service top drive. 0.0 0.0 11:00 11:30 11/3/2016 11/3/2016 5.25 SLOT PLUG TRIP T Make up Baker MSC cutter assembly 0.0 9,186.5 11:30 16:45 and RIH on 4"DP stands from derrick to 9186.5'.PUW 170k,SOW 97k, monitoring displacement on pit#5 Note:Cameron hand pressure tested packoff to confirm it was still holding, 5000 psi for 15 min-good test. 11/3/2016 11/3/2016 1.25 SLOT PLUG CPBO T Spot cutter at 9186.5'.Perform casing 9,186.5 9,186.5 16:45 18:00 cut w/8 bpm, 1992 psi, 12%F/O,80 rpm,9k Tq.Saw pressure gradually drop to 1512 psi.Slacked off into cut w/pumps on and no rotary and saw it take 5k weight.Pick up and observe pressure increase,confirming cut. OA pressure=95 psi-did not see any increase to indicate communication w/ IA. 11/3/2016 11/3/2016 0.50 SLOT PLUG CIRC T Close annular,line up to circulate 9,186.5 9,186.5 18:00 18:30 down DP/IA taking returns through OA to kill tank.Pressure up to 1000 psi- no circulation observed at OA w/ pressure at 0 psi. Note:Small amount of diesel bled back to surface when OA was initially opened to kill tank.With 12.2ppg mud in hole and 1000 psi on pumps,we should have—2000 psi differential to OA 11/3/2016 11/3/2016 1.00 SLOT PLUG CPBO T Pull up to 9125',PUW 163k,SOW 9,186.5 9,125.0 18:30 19:30 99k.Spot cutter at 9125'and perform 2nd casing cut w/6 bpm, 1550 psi, 10%F/O,80 rpm,9k Tq.Saw pressure gradually drop to 1049 psi. Slaccked off into cut w/pumps on and no rotary and saw it take 5k weight. Pick up and observe pressure increase,confirming cut. 11/3/2016 11/3/2016 0.25 SLOT PLUG CIRC T Close annular,line up to circulate 9,125.0 9,125.0 19:30 19:45 down DP/IA taking returns through OA to kill tank.Pressure up to 1000 psi- no circulation observed at OA w/ pressure at 0 psi. Note:With 12.2ppg mud in hole and 1000 psi on pumps,we should have —2000 psi differential to OA 11/3/2016 11/3/2016 1.25 SLOT PLUG CIRC T Discuss path forward with town.Drop 9,125.0 9,125.0 19:45 21:00 ball and pump down to open circ sub above cutters.Circulate 1 x BU at 8 bpm, 1400 psi, 12%F/0, 12.1+ppg in/out. 11/3/2016 11/3/2016 0.50 SLOT PLUG OWFF T Monitor well for flow-static.SIMOPS 9,125.0 9,125.0 21:00 21:30 bring on mud and prep for displacement.B/D kill line. Page 10/55 Report Printed: 12/28/2016 Aerations Summary (with Timelog [3epths) rpt 2S-13 ConocoPhitiips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 11/3/2016 11/3/2016 0.25 SLOT PLUG SFTY T Hold PJSM for displacing to 10.5ppg 9,125.0 9,125.0 21:30 21:45 LSND 11/3/2016 11/3/2016 1.25 SLOT PLUG DISP T Displace well from 12.2ppg Warp 9,125.0 9,125.0 21:45 23:00 WBM to 10.5ppg LSND w/8.4 bpm, 1570 psi dropping to 1280 psi, 14% F/O.Shut down as LSND was starting to come back to allow for moving mud in pits/rockwasher. 11/3/2016 11/3/2016 0.25 SLOT PLUG OWFF T Monitor well for flow-observe slight 9,125.0 9,125.0 23:00 23:15 flow out and small amount of diesel breaking out at surface.SIMOPS offload mud to vac truck. OA pressure=420 psi. 11/3/2016 11/3/2016 0.25 SLOT PLUG CIRC T Circulate/condition mud w/8 bpm, 9,125.0 9,125.0 23:15 23:30 1148 psi, 12%F/O,observe 10.5ppg in/out. OA pressure=drop to 380 psi 11/3/2016 11/4/2016 0.50 SLOT PLUG OWFF T Monitor well for flow-observe slight 9,125.0 9,125.0 23:30 00:00 flow out.Bleed off OA pressure from 380 psi to 200 psi and continue to monitor.Observe flow out stop-well static. Note:Observe small amount of diesel breaking out in mud at surface. 11/4/2016 11/4/2016 4.50 SLOT PLUG TRIP T Pull OOH racking back 4"DP f/9125' 9,125.0 0.0 00:00 04:30 to surface,monitoring displacement on trip tank. 11/4/2016 11/4/2016 1.00 SLOT PLUG -BHAH T Inspect cutters-observe good 0.0 0.0 04:30 05:30 indication that casing was successfully cut.L/D circ sub and re-dress cutters. 11/4/2016 11/4/2016 4.00 SLOT PLUG TRIP T RIH w/MSC cutter assembly on 4"DP 0.0 8,880.0 05:30 09:30 stands to 8880'MD,monitoring displacement on trip tank. 11/4/2016 11/4/2016 0.50 SLOT PLUG CPBO T Spot cutter at 8880'MD.PUW 152k, 8,880.0 8,880.0 09:30 10:00 SOW 101k,ROT 118k,7k Tq.Perform casing cut w/8 bpm,ICP 1910 psi, 13%F/O,80 rpm,7k Tq.Saw pressure drop to 1595 psi over 1 minute and then quickly fall to 1276 psi.Observed OA pressure increase from 0 psi to 950 psi. 11/4/2016 11/4/2016 0.50 SLOT PLUG CIRC T Hold PJSM for displacing OA to kill 8,880.0 8,880.0 10:00 10:30 tank.Close annular,line up to circulate down DP taking returns through OA to kill tank.Circulate 10 bbls to kill tank,holding 950 psi on choke manifold,to confirm communication with OA. Page 11/55 Report Printed: 12/28/2016 •0 Operations Summary (with Timelog ppths) 2S-13 11 Con ocoPhitlips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2016 11/4/2016 3.75 SLOT PLUG DISP T Displace OA to 10.5ppg LSND, 8,880.0 8,880.0 10:30 14:15 maintaining 950-450 psi backpressure throughout displacement,staging pumps up to 5 bpm, 1386 psi. Pump 35 bbls Hi-Vis Deepclean pill followed by 274 bbls 10.5ppg LSND.Shut down and suck diesel mixture out of kill tank.Continue pumping 279 bbls 10.5ppg LSND at 5 bpm, 1122 psi until MW 10.5ppg coming out at tank. 11/4/2016 11/4/2016 1.25 SLOT PLUG OWFF T Monitor well for flow-observe slight 8,880.0 8,815.0 14:15 15:30 flow back and slow u-tubing of fluid up drill string.Rack back stand,blow down topdrive,and continue monitoring well for flow.Observe flow back out of OA continually decrease to static and u-tube up drill string stop. 11/4/2016 11/4/2016 3.00 SLOT PLUG TRIP T Pull OOH racking back 4"DP f/8815'- 8,815.0 3,880.0 15:30 18:30 3880',PUW 150k,SOW 111k, monitoring displacement on trip tank. Total of 61 x stands racked in derrick. 11/4/2016 11/4/2016 3.00 SLOT PLUG PULD T Pull OOH laying down 4"DP f/3880'- 3,880.0 40.0 18:30 21:30 40',monitoring displacement on trip tank. 11/4/2016 11/4/2016 0.25 SLOT PLUG BHAH T Lay out MSC cutter and stablizer and 40.0 0.0 21:30 21:45 clear floor. 11/4/2016 11/4/2016 1.00 SLOT PLUG WWWH T Make up stack washer and jet stack 0.0 0.0 21:45 22:45 clean w/450 gpm,45 psi, 16%F/O, 50 rpm,0.3k Tq.LID same,blow down top drive,kill and choke lines. 11/4/2016 11/4/2016 0.50 SLOT PLUG RURD T Change out elevators for 5",pull 0.0 0.0 22:45 23:15 wearbushing and lay out same. 11/4/2016 11/5/2016 0.75 SLOT PLUG BOPE T Change out upper 3-1/2"x 6"VBR's to 0.0 0.0 23:15 00:00 7-5/8"solid body casing rams. SIMOPS Change out saver sub from XT39 to 4-1/2"IF. 11/5/2016 11/5/2016 2.00 SLOT PLUG BOPE T Change out upper 3-1/2"x 6"VBR's to 0.0 0.0 00:00 02:00 7-5/8"solid body casing rams. SIMOPS Change out saver sub from XT39 to 4-1/2"IF. 11/5/2016 11/5/2016 1.00 SLOT PLUG BOPE T Drain stack,Make up 7-5/8"test joint, 0.0' 0.0 02:00 03:00 R/U test assembly,and perform body test. 11/5/2016 11/5/2016 0.50 SLOT PLUG BOPE T Test annular and casing rams w/7- 0.0 0.0 03:00 03:30 5/8"test joint and 5"dart valve to 250/3500 psi 5/5 min-good test. Note:4-1/2"IF TIW unable to test- make up XO on tested XT39 TIW 11/5/2016 11/5/2016 0.50 SLOT PLUG BOPE T R/D test equipment and pull test plug. 0.0 0.0 03:30 04:00 11/5/2016 11/5/2016 2.50 SLOT PLUG WWSP T C/O elevators,pick up 5"DP double 0.0 0.0 04:00 06:30 and pack off retrieval tool.RIH and pull packoff,35k over block weight to pull free.LID packoff and running tool. SIMOPS:Rig up casing pulling equipment. Page 12/55 Report Printed: 12/28/2016 ' Operations Summary (with TimelogIpths) 0 t 2S-13 ConoctsPhiiiiias Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/5/2016 11/5/2016 0.50 SLOT PLUG PULL T RIH w/Baker spear on 5"DP and 0.0 8,875.0 06:30 07:00 spear casing below hanger.Pull hanger free,248k PUW.Pick up 5'. 11/5/2016 11/5/2016 2.00 SLOT PLUG CIRC T Line up and circulate 1 x surface-to- 8,875.0 8,875.0 07:00 09:00 surface volume at 489 gpm,419 psi until even 10.5ppg in/out 11/5/2016 11/5/2016 1.50 SLOT PLUG PULL T Pull hanger to floor.Observed hanger 8,875.0 8,843.0 09:00 10:30 catching up in BOP stack-rig up tuggers to help keep it centered. 11/5/2016 11/5/2016 0.50 SLOT PLUG PULL T Release spear and L/D 5"DP,spear, 8,843.0 8,843.0 10:30 11:00 and hanger. 11/5/2016 11/5/2016 5.00 SLOT PLUG PULL T Pull OOH w/7 5/8"29.7# L-80 8,843.0 5,268.0 11:00 16:00 Dopeless Hyd 563 casing f/8843'- 5268',PUW 240k,SOW 155k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 1.00 SLOT PLUG CIRC T Observe well u-tubing up the 7-5/8" 5,268.0 5,268.0 16:00 17:00 casing.Stab floor valve,make up top drive and circulate string volume at 510 gpm,250 psi,16%F/O.Observe even 10.5ppg in/out.R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 1.75 SLOT PLUG PULL T Pull OOH w/7 5/8"29.7# L-80 5,268.0 3,272.0 17:00 18:45 Dopeless Hyd 563 casing f/5268'- 3272',PUW 133k,SOW 115k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 0.75 SLOT PLUG CIRC T Observe well u-tubing up the 7-5/8" 3,272.0 3,272.0 18:45 19:30 casing.Stab floor valve,make up top drive and circulate string volume at 510 gpm, 137 psi, 16%F/O.Observe even 10.5ppg in/out.R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 0.75 SLOT PLUG PULL T Pull OOH w/7 5/8"29.7# L-80 3,272.0 2,040.0 19:30 20:15 Dopeless Hyd 563 casing f/3272'- 2040',PUW 90k,SOW 80k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 0.75 SLOT PLUG CIRC T Observe well u-tubing up the 7-5/8" 2,040.0 2,040.0 20:15 21:00 casing.Stab floor valve,make up top drive and circulate surface-to-surface volume at 510 gpm,93 psi, 16%F/O. Observe even 10.5ppg in/out.R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 2.25 SLOT PLUG PULL T Pull OOH w/7 5/8"29.7# L-80 2,040.0 0.0 21:00 23:15 Dopeless Hyd 563 casing f/2040'to surface,monitoring displacement on trip tank and strapping joints in pipe shed. Total of 215 x joints,1 x cut joint,and 3 x hydroform centralizers laid out.Cut joint=35.25'.Cement residue observed on last 3 x joints and on cut joint. 11/5/2016 11/6/2016 0.75 SLOT PLUG RURD T Rig down casing tools and stage to 0.0 0.0 23:15 00:00 side on rig floor.Clean/clear rig floor. 11/6/2016 11/6/2016 1.50 SLOT PLUG BOPE T Flush stack and C/O upper rams to 3- 0.0 0.0 00:00 01:30 1/2"X 6"VBRs. 11/6/2016 11/6/2016 0.25 SLOT PLUG BOPE T R/U to test rams and annular with 5" 0.0 0.0 01:30 01:45 test joint. Page 13/55 Report Printed: 12/28/2016 0 !perations Summary (with Timelog�pths) 2S-13 conoccPhitlips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2016 11/6/2016 0.75 SLOT I PLUG BOPE T Test lower rams,upper rams and 0.0 0.0 01:45 02:30 annular with 5"test joint.Test rams and 5"floor valve to 250/3500 psi and annular to 250/2500 psi. 11/6/2016 11/6/2016 0.50 SLOT PLUG RURD T Install 12.5"ID wear bushing. 0.0 0.0 02:30 03:00 11/6/2016 11/6/2016 1.50 SLOT PLUG 'BHAH T M/U Baker fishing BHA as per Baker 0.0 235.0 I 03:00 04:30 rep,Spear,Bumper sub,Oil jar,Circ sub,6 x 6-1/4"spiral DC's,and Accelerator jar. 11/6/2016 11/6/2016 7.75 SLOT PLUG PULD T RIH picking up 5"DP singles from 235.0 8,855.0 04:30 12:15 shed f/235'-8760'MD,monitoring displacement on trip tank.Total of 91 x stands and 2 x singles 5"DP picked up. 11/6/2016 11/6/2016 1.50 SLOT PLUG CIRC T Circulate hole clean w/676 gpm,ICP 8,855.0 8,855.0 12:15 13:45 1450psi,FCP 1371 psi, 18%F/O,MW 10.5ppg in/out,total 1120 bbls circulated. Note:observed a heavy spot of 10.7+ppg at bottoms up. 11/6/2016 11/6/2016 2.25 SLOT PLUG `JAR T RIH and confirm depth of fish-no-go 8,855.0 8,880.0 P 9 13:45 16:00 out at 8880'.PUW 211k,SOW 135k. Engage spear and attempt to jar free 7 -5/8"fish.Jar at 280k and then P/U to 425k.Stage up to jarring at 410k and continue picking up to 425k after each fire.Fire jars total of 60 x times. Unable to jar fish free. 11/6/2016 11/6/2016 0.25 SLOT PLUG -PULD T Disengage spear and L/D 2 x 5"DP 8,880.0 8,855.0 16:00 16:15 singles,PUW 211k. 11/6/2016 11/6/2016 1.25 SLOT PLUG SFTY T Perform post-jarring derrick 8,855.0 8,855.0 16:15 17:30 inspection.SIMOPS L/D casing power tongs off rig floor. 11/6/2016 11/6/2016 4.00 SLOT PLUG TRIP T POOH racking back 5"DP stands f/ 8,855.0 235.0 17:30 21:30 8855'-235'MD,monitoring displacement on trip tank. 11/6/2016 11/6/2016 1.00 SLOT PLUG BHAH T L/D fishing BHA as per Baker rep f/ 235.0 0.0 21:30 22:30 235'to surface.Observe damage to packoff element on spear 11/6/2016 11/6/2016 1.00 SLOT PLUG BHAH T Clean and clear rig floor and mobilize 0.0 0.0 22:30 23:30 clean out BHA to rig floor. 11/6/2016 11/7/2016 0.50 SLOT PLUG BHAH T P/U cleanout BHA as per Baker rep. 0.0 46.0 23:30 00:00 M/U junk mill,watermelon mill,casing scraper,float,bumper sub,oil jar,and circ sub. 11/7/2016 11/7/2016 0.75 SLOT PLUG BHAH T Finish M/U cleanout BHA as per Baker ' 46.0 46.0 00:00 00:45 rep, M/U junk mill,watermelon mill, casing scraper,float,bumper sub,oil jar,and circ sub. 11/7/2016 11/7/2016 0.75 SLOT PLUG PULD T RIH w/cleanout BHA picking up 18 x 46.0 605.0 00:45 01:30 4"HWDP jts from shed f/46'-605'MD, monitoring displacement on pit#5. 11/7/2016 11/7/2016 1.25 SLOT PLUG PULD T RIH w/cleanout BHA picking up 42 x 605.0 1,933.0 01:30 02:45 4"DP jts from shed f/605'-1933'MD, monitoring displacement on pit#5.Fill pipe and B/D topdrive. Page 14/55 Report Printed: 12/28/2016 1114 arg Aerations Summary (with TimelogIpths) 0 2S-13 Conoccehi[iips Ai.:sk:s Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/7/2016 11/7/2016 0.50 SLOT PLUG SVRG T Service rig,grease crown,top drive, 1,933.0 1,933.0 02:45 03:15 and blocks. 11/7/2016 11/7/2016 2.75 SLOT PLUG TRIP T RIH w/cleanout BHA on 4"DP stands 1,933.0 6,448.0 03:15 06:00 f/1933'-6448'MD,filling pipe every 20 x stands and monitoring displacement on pit#5 11/7/2016 11/7/2016 1.00 SLOT PLUG REAM T Tag up at 6448'MD WI 10k 6,448.0 6,475.0 06:00 07:00 downweight,observe 8k overpull. Obtain parameters PUW 167k,SOW 120k,ROT 143k,30 rpm,7k Tq. Stage up pumps to 6 bpm,330 psi, 8%F/O and stage up rotary to 30 rpm, 8-12k Tq. Ream across section f/ 6445-6551'several times then continue down to 6475'. Note:Watermelon mill 12.8'above junk mill on btm 11/7/2016 11/7/2016 1.50 SLOT PLUG TRIP T RIH w/cleanout BHA on 4"DP stands 6,475.0 8,846.0 07:00 08:30 f/6475'-8846'MD,monitoring displacement on pit#5. 11/7/2016 11/7/2016 0.50 SLOT PLUG CIRC T Fill pipe,obtain parameters PUW 8,846.0 8,880.0 08:30 09:00 220k,SOW 138k.Stage up pumps to 5 bpm,344 psi,7%F/O,wash down and tag top of 7-5/8"fish @ 8880'MD w/5k. 11/7/2016 11/7/2016 1.75 SLOT PLUG CIRC T R/B stand and P/U single to allow for 8,880.0 8,846.0 09:00 10:45 reciprocating full stand.Stage up to 6 bpm,400 psi,8%F/O,40 rpm, 10-12k Tq and work section from 8845-8875'. Kill rotary,continue staging up pumps to 12 bpm,930 psi, 16%F/O and reciprocate f/8800'-8875'.Circulate 1 x surface-to-surface volume. 11/7/2016 11/7/2016 1.00 SLOT PLUG OWFF T Monitor well for flow-static. L/D 8,846.0 8,846.0 10:45 11:45 single,pump dry job,and B/D top drive. 11/7/2016 11/7/2016 2.75 SLOT PLUG TRIP T POOH racking back 5"DP f/8846'- 8,846.0 605.0 11:45 14:30 605'MD,monitoring displacement on trip tank. 11/7/2016 11/7/2016 0.50 SLOT PLUG TRIP T POOH racking back 5"HWDP f/605'- 605.0 46.0 14:30 15:00 46'MD,monitoring displacement on trip tank. 11/7/2016 11/7/2016 1.25 SLOT PLUG BHAH T Lay down cleanout BHA as per Baker, 46.0 0.0 15:00 16:15 monitoring displacement on trip tank. Clean/clear rig floor of BHA tools. 11/7/2016 11/7/2016 2.00 SLOT PLUG ELOG T Mobilize E-line tools to rig floor and 0.0 0.0 16:15 18:15 R/U for running E-line. Page 15155 Report Printed: 12/28/2016 0 Iterations Summary (with Timelogepths) 2S-13 ConocoPhilliprs Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/7/2016 11/7/2016 5.25 SLOT PLUG ELOG T RIH w/E-Line EMIT tool and tag up on 0.0 0.0 18:15 23:30 7-5/8"stump.Log section at various frequencies and running speeds as per SLB E-line to obtain correct data for EMIT analysis.POOH and L/D tools. Note:No clear indications observed to show centralizer placement behind pipe.However,SLB E-Line confirmed 10-3/4"collars are at 8836.75', 8797.75',&8758.75'MD w/D142's RKB.Unable to clearly indicate depth of lowest collar w/EM tool,but using joint length from tally,it is at 8873.55' MD w/D142's RKB. 11/7/2016 11/8/2016 0.50 SLOT PLUG ELOG T R/D E-line and clear rig floor. 0.0 0.0 23:30 00:00 11/8/2016 11/8/2016 2.50 SLOT PLUG FLOG T Remove bell nipple,nipple down dutch 0.0 0.0 00:00 02:30 riser system and remove mouse hole. 11/8/2016 11/8/2016 1.50 SLOT PLUG MPDA T Nipple up RCD on top of annular. 0.0 0.0 02:30 04:00 Obtain measurements needed to modify trip nipple and send over to shop.Install mouse hole. 11/8/2016 11/8/2016 1.50 SLOT PLUG SLPC T PJSM,Slip and cut 102'of drilling line. 0.0 0.0 04:00 05:30 11/8/2016 11/8/2016 0.25 SLOT WHDBOP RURD T Pull wear bushing and install test plug. 0.0 0.0 05:30 05:45 11/8/2016 11/8/2016 0.75 SLOT WHDBOP MPDA T Install test cap on RCD and purge air 0.0 0.0 05:45 06:30 from BOP stack.Pressure test RCD to 250/1500 psi,good test. Page 16/55 Report Printed: 12/28/2016 Aperations Summary (with Timelo the )0.2 2S-13 ConocoPhitliprs Al_�ks Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/8/2016 11/8/2016 4.00 SLOT WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 06:30 10:30 Chuck Scheve.Tested with 5"test joint.250/3500 psi,charted for 5 minutes each. Test#1 Blind rams,CV#12,13 and . 14,Kill mud manifolds and 4-1/2"Dart Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and 4-1/2"IF Floor valve. Test#3- CV#8,#10 and HCR Kill, Test#4-CV#6,#7 and Manual kill Test#5- Super Choke& Manual operated choke to 2000 PSI. Test#6-CV#2,#5&Annular Test#7-Upper pipe rams,CV#3,4,6 and 1. Test#8-HCR Choke Test#9-Manual choke and Upper IBOP Test#10-Lower pipe rams and lower IBOP Perform Koomey draw down test. Observed initial system pressure at 3000 psi,after closure 1650 psi,200 psi increase in 8 seconds,and full pressures at 51 seconds. Observed 6 nitrogen bottles with an average PSI of 2350 PSI.Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 11/8/2016 11/8/2016 1.00 SLOT WHDBOP RURD T Remove test plug and install wear 0.0 0.0 10:30 11:30 bushing.Blow down choke,kill and top drive.L/D 5"test joint. 11/8/2016 11/8/2016 1.00 SLOT WHPST BHAH T Picked up BHA componets to Rig 0.0 0.0 11:30 12:30 Floor via Beaver Slide. 11/8/2016 11/8/2016 3.00 SLOT WHPST BHAH T Made up BHA and 18 jts 5"HWDP per 0.0 736.0 12:30 15:30 Baker Rep. 11/8/2016 11/8/2016 0.75 SLOT WHPST TRIP T RIH with Whipstock from 736'to 736.0 1,495.0 15:30 16:15 1,495' 11/8/2016 11/8/2016 0.25 SLOT WHPST DHEQ T Shallow tested MWD. 1,495.0 1,495.0 16:15 16:30 11/8/2016 11/8/2016 5.50 SLOT WHPST 'TRIP T RIH with Whipstock from 1495'to 1,495.0 8,880.0 16:30 22:00 8,880'filling DP every 20 stands. 11/8/2016 11/8/2016 0.75 SLOT WHPST SRVY T Survey and orient Whipstock to 19 8,880.0 8,845.0 22:00 22:45 Deg left of High Side.Set anchor and pull test.Sheared bolt. 11/8/2016 11/9/2016 1.25 SLOT WHPST MILL T Milled Window from 8,845'to 8,846'. 8,845.0 8,846.0 22:45 00:00 655 GPM, 1640 PSI,2 K WOB,100 RPM, 18 K torque.Up Wt 215K DW 135K Rot Wt 170K. 11/9/2016 11/9/2016 5.50 SLOT WHPST MILL T Milled Window from 8,846'to 8,861'. 8,846.0 8,861.0 00:00 05:30 553 GPM,1215 PSI,6 K WOB,90 RPM,20 K torque.Up Wt 215K DW 135K Rot Wt 170K. Page 17/55 Report Printed: 12/28/2016 • Operations Summary (with Timelogfpths) 0.4 2S-13 +CortocoPhiiliips R6�k.a Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log • Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/9/2016 11/9/2016 4.00 SLOT WHPST MILL T Milled Window from 8,861'to 8,889'. K` 8,861.0 8,889.0 05:30 09:30 550-746 GPM, 1215-2013 PSI, 15 K WOB,90 RPM, 17 K torque.Up Wt 215K DW 135K Rot Wt 170K.Upper Mill out into open hole @ 8889'MD. Top of window @ 8847'MD,Bottom of window @ 8867'MD 11/9/2016 11/9/2016 4.00 SLOT WHPST DDRL T Milled 15'of gauge 9-7/8"open hole 8,889.0 8,904.0 09:30 13:30 from 8,889'to 8,904'.500GPM,1138 PSI, 13%FO,15 K WOB, 130 RPM, 17 K torque.Up Wt 215K DW 135K Rot Wt 170K. 11/9/2016 11/9/2016 1.00 SLOT WHPST REAM T Worked Mills through window and 8,904.0 8,847.0 13:30 14:30 Dressed window with and without pumps.750 GPM @ 2,085 PSI,90 RPM. 11/9/2016 11/9/2016 0.75 SLOT WHPST CIRC T Pulled from top of window @ 8847'to 8,847.0 8,823.0 14:30 15:15 8823'and CBU 800 GPM 2282 PSI. 11/9/2016 11/9/2016 1.00 SLOT WHPST -FIT T RU and FIT 14.7 PPG EMW. 8,823.0 8,823.0 15:15 16:15 11/9/2016 11/9/2016 0.50 SLOT WHPST OWFF T Observed well Static. 8,823.0 8,823.0 16:15 16:45 11/9/2016 11/9/2016 3.75 SLOT WHPST TRIP T POOH from 8,823'to 181'. 8,823.0 181.0 16:45 20:30 11/9/2016 11/9/2016 1.00 SLOT WHPST BHAH T POOH cleaning Magnets from 181'to 181.0 120.0 20:30 21:30 120'.Slots were full of metal shavings. 11/9/2016 11/9/2016 1.50 SLOT WHPST BHAH T Laid down BHA. 120.0 0.0 21:30 23:00 11/9/2016 11/10/2016 1.00 SLOT WHPST BHAH T Cleared BHA componets off Rig Floor. 0.0 0.0 23:00 00:00 11/10/2016 11/10/2016 1.00 SLOT WHPST WWWH T M/U stack washer on MI Swaco 0.0 0.0 00:00 01:00 magnets.Wash BOP stack to clean metal cuttings out of stack from milling casing.L/D assembly. 11/10/2016 11/10/2016 2.00 SLOT WHPST BHAH T M/U drilling BHA and HWDP to 760' 0.0 0.0 01:00 03:00 MD 11/10/2016 11/10/2016 0.75 SLOT WHPST TRIP T RIH w/5"DP f/760'MD to 1700'MD. 0.0 1,700.0 03:00 03:45 11/10/2016 11/10/2016 0.25 SLOT WHPST DHEQ T Shallow hole test MWD as per SLB, 1,700.0 1,700.0 03:45 04:00 good test. 11/10/2016 11/10/2016 3.00 SLOT WHPST TRIP T RIH w/5"DP f/1700'MD to 8814'MD, 1,700.0 8,814.0 04:00 07:00 fill pipe every 20 stands.Observed proper hole fill. 11/10/2016 11/10/2016 0.75 SLOT WHPST MPDA T Remove trip nipple and install MPD 8,814.0 8,814.0 07:00 07:45 bearing as per MPD personal. 11/10/2016 11/10/2016 1.25 SLOT WHPST MPDA T Establish circulation @ 750 gpm=2480 8,814.0 8,814.0 07:45 09:00 psi.Calibrate MPD chokes as per rig engineer.Break in MPD element @ 40 , rpm's.Sent downlink to ensure tool is in neutral.P/U=220K,S/0=143K. 11/10/2016 11/10/2016 0.75 SLOT WHPST CIRC T Obtain slow pump rates @ 8814'MD, 8,814.0 8,814.0 09:00 09:45 5786'TVD,MW=10.5 ppg MP#1:30 spm=260 psi,40 spm=330 psi MP#2:30 spm=260 psi,40 spm=330 psi Page 18/55 Report Printed: 12/28/2016 r ¶erations •Summary (with Timelog Depths) i~14 2S-13 ConocoPhitlipss Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/10/2016 11/10/2016 0.75 SLOT WHPST TRIP T Trip BHA though window,Top @ 8,814.0 8,838.0 09:45 10:30 8847'MD,Bottom @ 8867'MD.Set down 10K on under gauge hole© 8880'MD.P/U though window to 8840'MD,observed 15K over pull when pulling bit though bottom of window.RIH back to 8880'MD,set down 10K.Lower stabilizer still on the bottom of slide,decision made to P/U and get the stabilizer higher on slide before reaming down to open up under gauge hole. • 11/10/2016 11/10/2016 0.50 SLOT WHPST REAM T Shut off Pump and Rotation and 8,838.0 8,887.0 10:30 11:00pulled up to TOW @ 8,845'5K overpull.Ran back in to 8,887'. 11/10/2016 11/10/2016 1.00 INTRM5 DRILL REAM T Ream from 8,887'to 8,904'50 RPM 8,887.0 8,904.0 11:00 12:00 Torq 15K 551 GPM PP 1586 PSI WOB 2-4 K. 11/10/2016 11/10/2016 6.00 INTRM1 DRILL DDRL T Directional Drilled from 8,904'to 8,904.0 9,025.0 12:00 18:00 9,025'MD,5,874'TVD,GPM 600,PP 1900 PSI,RPM 50-100,TQ on Btm 15-17K,Off 14K,WOB 5-7K,UW 225K,DW 141K,RW 167K,ECD 11.3,Max Gas 39 units MPD 400 psi, ADT 5.4 Hrs 11/10/2016 11/11/2016 6.00 INTRM1 DRILL DDRL T Directional Drilled from 9,025'to 9,025.0 9,314.0 18:00 00:00 9,314'MD,5,999'TVD,GPM 650,PP 2355 PSI,RPM 100,TQ on Btm 15- 18K,Off 14K,WOB 12-17K,UW 215K, DW 141K,RW 167K,ECD 11.2 -11.8,Max Gas 39 units MPD 400 psi,ADT 4.69 Hrs 11/11/2016 11/11/2016 6.50 INTRM1 DRILL DDRL T Directional Drilled from 9,314'to 9,314.0 9,712.0 00:00 06:30 9,712'MD,6,156'TVD,GPM 650,PP 2350 PSI,RPM 130,TQ on Btm 16- 18K,Off 14K,WOB 18K,UW 213K, DW 140K,RW 172K,ECD 11.75,Max Gas 30 units MPD 400 psi,ADT 4.81 Hrs 11/11/2016 11/11/2016 3.00 INTRM1 DRILL WAIT T Circulated while waiting for survey 9,712.0 9,712.0 06:30 09:30 corrections from Schlumberger,653 ' GPM 2400 psi 80 RPM Tq 12K. 11/11/2016 11/11/2016 2.50 INTRM1 DRILL DDRL T Directional Drilled from 9,712'to 9,712.0 9,854.0 09:30 12:00 9,854'MD,6,225'TVD,GPM 650,PP 2460 PSI,RPM 130,TQ on Btm 16- 18K,Off 14K,WOB 18K,UW 219K, DW 145K,RW 170K,ECD 11.7 to 11.9,Max Gas 183 units MPD 400 psi, ADT 1.35 Hrs mud lost for 12 Hrs 0 Bbls. 11/11/2016 11/11/2016 7.50 INTRM1 DRILL DDRL T Directional Drilled from 9,854'to 9,854.0 10,414.0 12:00 19:30 10414'MD,6,351'TVD,GPM 650 to 700,PP 2800 PSI,RPM 130,TQ on Btm 16-24K,Off 15 to 18K,WOB 15 to 18K,UW 242K,DW 122K,RW 168K,ECD 11.7 to 11.9,Max Gas 537 units MPD 300 psi,ADT 5.81 Hrs 11/11/2016 11/11/2016 1.50 INTRM1 CASING CIRC T CBU 700 GPM,2785 PSI, 130 RPM, 10,414.0 10,414.0 19:30 21:00 20K Tq,Took Survey and SPR. Page 19/55 Report Printed: 12/28/2016 4 i Operations Summary (with Timelog Depths) t 2S-13 Conoco hillips AI.xAs Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/11/2016 11/11/2016 0.75 INTRM1 CASING OWFF T Finger Print Test.Closed choke 10,414.0 10,414.0 21:00 21:45 (MPD)for 5 Min build up 0 PSI, opened for 5 Min No flow 1 PSI. Closed for final build 0 PSI 5 Min. Opened for 10 Min no flow. 11/11/2016 11/12/2016 2.25 INTRMI CASING CIRC T Circulate and increase MW from 10.7 10,414.0 10,414.0 21:45 00:00 PPG to 11 PPG for Trip Margin.655 GPM,2610 PSI,60 RPM,Tq 13 to 16K, Up 242 Dn 122,Rt 170,ECD 11.6 to 11.9.total mud loss for 12 Hrs 87 Bbl. 11/12/2016 11/12/2016 1.00 INTRM1 CASING CIRC T Circulate and increase MW from 10.7 10,414.0 10,414.0 00:00 01:00 PPG to 11 PPG for Trip Margin.655 GPM,2610 PSI,60 RPM,Tq 13 to 16K,Up 242 Dn 122,Rt 170,ECD 11.6 to 11.9 11/12/2016 11/12/2016 0.50 INTRM1 CASING OWFF T Observed well for 30 min.No Flow. 10,414.0 10,414.0 01:00 01:30 11/12/2016 11/12/2016 2.00 INTRM1 CASING SMPD T POOH Strip out from 10,414'to 9,854' 10,414.0 9,854.0 01:30 03:30 100 psi Back pressure with MPD. Over pull to 30K.Worked tight spots. 11/12/2016 11/12/2016 5.25 INTRM1 CASING BKRM T Backreamed out of the hole From 9,854.0 8,783.0 03:30 08:45 9,854'to 8,783'.550 GPM 1875 psi Slowed GPM to 366 with 945 psi to come through window,5-10 K overpull.UW 240K DW 138K,60 RPM. 11/12/2016 11/12/2016 2.00 INTRM1 CASING CIRC T CBU X 2 650 GPM 2445 psi, 140 8,783.0 8,783.0 08:45 10:45 RPM, 11/12/2016 11/12/2016 0.50 INTRMI CASING OWFF T OWFF for 30 Min.Lost.5 Bbl. 8,783.0 8,783.0 10:45 11:15 11/12/2016 11/12/2016 1.25 INTRM1 CASING MPDA T Pulled RCD and nipple. Installed Trip 8,783.0 8,783.0 11:15 12:30 nipple. 11/12/2016 11/12/2016 2.00 INTRM1 CASING TRIP T POOH from 8,387'to 7,295'UW 205K 8,783.0 7,295.0 12:30 14:30 DW 130K.Dropped 2 7/8"Rabbit on Stand 83. 11/12/2016 11/12/2016 0.50 INTRM1 CASING CIRC T Pumped 20 Bbl Dry Job 5 BPM 340 7,295.0 7,295.0 14:30 15:00 psi. 11/12/2016 11/12/2016 4.25 INTRM1 'CASING TRIP T POOH from 7,295'to 760'.UW 82K 7,295.0 760.0 15:00 19:15 DW 80K.Recovered Rabbit at HWDP. 11/12/2016 11/12/2016 0.50 INTRM1 CASING RURD T Recovered Stripping Rubber and RU 760.0 760.0 19:15 19:45 to LD HWDP. 11/12/2016 11/12/2016 2.75 INTRMI CASING BHAH T POOH Laying Down BHA from 760'to 760.0 0.0 19:45 22:30 0'. 11/12/2016 11/13/2016 1.50 INTRM1 CASING BOPE T PJSM and Changed Upper Rams to 7 0.0 0.0 22:30 00:00 5/8". 11/13/2016 11/13/2016 0.50 INTRM1 CASING BOPE T PJSM,Cont to change upper rams to 0.0 0.0 00:00 00:30 7-5/8"soild body rams. 11/13/2016 11/13/2016 1.00 INTRM1 CASING BOPE T Pull wear bushing and set test plug. 0.0 0.0 00:30 01:30 Rig up to test BOPE. 11/13/2016 11/13/2016 0.75 INTRM1 CASING BOPE T Test upper 7-5/8"pipe rams to 0.0 0.0 01:30 02:15 250/3500 psi and annular to 250/2500 psi with 7-5/8"test joint.Test replacement 4-1/2"IF floor valve to 250/3500 psi. 11/13/2016 11/13/2016 1.00-INTRM1 CASING BOPE T Rig down testing equipment and blow 0.0 0.0 02:15 03:15 down.Remove test plug and set 12- 1/2"ID wear bushing. Page 20/55 Report Printed: 12/28/2016 -' ! erations Summary (with Timelog!pths) 2S-13 �ocoPhiilips ,41.xk. Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/13/2016 11/13/2016 0.76 INTRMI CASING RURD T Rig up to run 7-5/8"liner.C/O to long 0.0 0.0 03:15 04:00 bails,casing elevators and R/U power tongs. 11/13/2016 11/13/2016 3.00 INTRM1 CASING PUTB T M/U Topco shoe,2 joints,WFT float 0.0 1,684.0 04:00 07:00 collar, 1 joint and BHI landing collar. Test floats,good.RIH w/7-5/8',29.7#, L-80 Hydril 563 casing t/surface to 1684'MD.P/U=87K,S/O=87K 11/13/2016 11/13/2016 0.50 INTRM1 CASING OTHR T Changed Handling tools and made up 1,684.0 1,717.0 07:00 07:30 Liner Hanger. 11/13/2016 11/13/2016 0.75 INTRMI CASING CIRC T Made up 1 stand DP and Broke 1,717.0 1,810.0 07:30 08:15 Circulatinon staging up to 6 BPM. 148 psi with 9%Flow. 11/13/2016 11/13/2016 6.25 INTRM1 CASING RUNL T RIH with Liner on DP from 1,810'to 1,810.0 8,369.0 08:15 14:30 8,369'.UW 240K DW 135K.Fill DP on the fly and top off every 10 Stands. 11/13/2016 11/13/2016 3.00 INTRM1 CASING CIRC T Circulate and condition mud staging 8,369.0 8,369.0 14:30 17:30 pump up to 6 BPH 449 psi.MW in 11.1 MW out 11.2.UW 214K DW 133K.FO 9-10%.7263 total strokes pumped. 11/13/2016 11/14/2016 6.50 INTRM1 CASING RUNL T. RIH with Liner on DP from 8,369'to 8,369.0 10,325.0 17:30 00:00 10,325'.UW 242K DW 132K.Fill DP on the fly and top off every 10 Stands.From 9,600'took 20 to 40K to push in.Running speed adjusted from 250'PH to 100 FPH to keep from stacking weight.Loss for tour 22 Bbls. 11/14/2016 11/14/2016 1.00 INTRM1 CASING RUNL T RIH with Liner on DP from 10,325'to 10,325.0 10,345.0 00:00 01:00 10,345'.UW 242K DW 132K.Fill DP on the fly and top off every 10 Stands.From 9,600'took 20 to 40K to push in.Running speed adjusted from 250'PH to 100 FPH to keep from stacking weight. 11/14/2016 11/14/2016 0.50 INTRMI CASING RUNL T Washed down from 10,345'to 10,414'. 10,345.0 10,414.0 01:00 01:30 Staged pump up to 4 BPM 520 psi UW 240k DW 130K tagged w 5K. 11/14/2016 11/14/2016 2.75 INTRMI CASING CIRC T CBU staging pump to 7BPM.615 psi. 10,414.0 10,403.0 01:30 04:15 with 10%FO.Attempted to recipricate but packed off while pulling up.Put pipe @ 10,403'and were able to increase rate to 7 BPM without packing off.Max Gas 397 units. 11/14/2016 11/14/2016 0.50 INTRMI CEMENT RURD T Laid down Single and made up Baker 10,403.0 10,403.0 04:15 04:45 Plug Dropping Head. 11/14/2016 11/14/2016 6.75 INTRM1 CEMENT CIRC T' Circulate and condition mud lowering 10,403.0 10,403.0 04:45 11:30 MW from 11.1 PPG to 10.5 PPG. Staged pump up to 7 BPM 690 PSI. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT SFTY T PJSM on Cementing. 10,403.0 10,403.0 11:30 12:00 1 Page 21/55 Report Printed: 12/28/2016 000..,2,,1. !perations Summary (with TimelogIpths) 2S-13 ccx►ocoPhiilip�s Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (YKB) End Depth(ftKB) 11/14/2016 11/14/2016 1.00 INTRM1 CEMENT CMNT ,T Schlumberger pumped 5 Bbls water. 10,403.0 8,687.1 12:00 13:00 Tested lines to 4000 psi.Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet.4.4 to 6 BPM.Dart launch confirmed for both Darts.Pumped 10 Bbls Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls.Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. 11/14/2016 11/14/2016 0.50 INTRMI CEMENT PACK T Pressured up to 3800 psi held 5 min 8,687.1 8,687.0 13:00 13:30 to set liner.Set down 60K and bled pressure.Checked floats good. Released from liner and set ZXP packer Disengaged from PBR pumpiong 2 BPM.Top of Liner @ 8687.08'. 11/14/2016 11/14/2016 1.50 INTRM1 CEMENT CIRC T PU 30'to 8657'.Circulated at 7 BPM 8,687.1 8,657.0 13:30 15:00 600 psi staging up to 15 BPM 1196 psi total of 7800 Stks. 11/14/2016 11/14/2016 0.50 INTRMI CEMENT RURD T Laid down 1 single and cement head. 8,657.0 8,595.0 15:00 15:30 11/14/2016 11/14/2016 1.00 INTRM1 CEMENT CIRC T Circulated staging up to 15 BPM 1190 8,595.0 8,595.0 15:30 16:30 psi total of 8900 Stks.Recip pipe 30'. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT OWFF , T' POOH 2 Stands and observe well for 8,595.0 8,433.0 16:30 17:00 10 min. No Flow. 11/14/2016 11/14/2016 0.75 INTRM1 CEMENT PRTS T RU and Test Liner Top 1000 psi for 10 8,433.0 8,433.0 17:00 17:45 Min.Good Test.RD test equipment. 11/14/2016 11/14/2016 0.75 INTRM1 CEMENT CIRC T Broke Circulation and pumped Dry 8,433.0 8,433.0 17:45 18:30 Job. 11/14/2016 11/15/2016 5.50 INTRM1 CEMENT PULD T POOH laying down 5"DP from 8,433' 8,433.0 3,000.0 18:30 00:00 to 3,000'. 11/15/2016 11/15/2016 3.50 INTRM1 CEMENT PULD T POOH laying down 5"DP and Baker 3,000.0 0.0 00:00 03:30 Running Tool from 3,000'to Surface. 11/15/2016 11/15/2016 1.50 INTRM1 CEMENT PULD T Laid down 15 Stands 5"DP from the 0.0 0.0 03:30 05:00 Derreck via mousehole. 11/15/2016 11/15/2016 0.50 INTRMI CEMENT WWWH T Made up Stack wash tool and washed 0.0 0.0 05:00 05:30 stack. 11/15/2016 11/15/2016 0.50 INTRMI CEMENT RURD T Cleared Rig floor and PU Casing 0.0 0.0 05:30 06:00 tools. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT SVRG T MP2 work on Topdrive and 0.0 0.0 06:00 06:30 Drawworks. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT RURD T Pulled Wearbushing. 0.0 0.0 06:30 07:00 11/15/2016 11/15/2016 0.50 INTRMI CEMENT RURD T RU to run casing. 0.0 0.0 07:00 07:30 11/15/2016 11/15/2016 0.50 INTRMI CEMENT HOSO T Made Dummy run with casing Hanger. 0.0 0.0 07:30 08:00 11/15/2016 11/15/2016 10.00 INTRMI CEMENT PUTB T,, Ran 7 5/8"29.7#L-80 HYD 563 0.0 8,658.0 08:00 18:00 Casing with Tieback seals from Surface to 8,658'.UW 261K DW 141K. Page 22/55 Report Printed: 12/28/2016 0 terations Summary (with Timelog 6epths) P 1 lti� 2S-13 Cono€oPhi Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/15/2016 11/15/2016 2.00 INTRM1 CEMENT HOSO T RU to circulate.RIH to locate Seals in 8,658.0 8,703.0 18:00 20:00 the PBR.Detected Seal engagment @ 8,694'.Picked up Jt 213 and located on no-go at 8,703'.Tally difference 6.89'Deep. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT PRTS T Closed Annulur and Tested 7 5/8"X 8,703.0 8,703.0 20:00 20:30 10 3/4"Annulus to 2,000 PSI for 10 Min. 11/15/2016 11/15/2016 1.00 INTRM1 CEMENT HOSO T Space out Casing with 2 Pups total 8,703.0 8,703.0 20:30 21:30 2.12'below the first full Jt.Landed Hanger and confirmed seal engagment with 200 PSI PT on annulus.Bled off after 10 Min on chart. 11/15/2016 11/15/2016 1.00 INTRM1 CEMENT HOSO T Picked up 10'and Made Dummy run 8,703.0 8,703.0 21:30 22:30 with Annular closed stripping and landed out Hanger. 11/15/2016 11/16/2016 1.50 INTRM1 CEMENT CRIH T' Picked up to 8,693'.Closed annular 8,703.0 8,693.0 22:30 00:00 and Reverse circulated 30 Bbls spacer pill followed by 175 Bbls of 300 Bbls of Inhibited Water @ 3 BPM.ICP 400 PSI FCP 565 PSI. 11/16/2016 11/16/2016 0.75 INTRM1 CEMENT CRIH T Circulated 125 Bbls of of Inhibited 8,693.0 8,693.0 00:00 00:45 Water @ 3.5 BPM.ICP 565 PSI FCP 670 PSI. 11/16/2016 11/16/2016 1.00 INTRM1 CEMENT .FRZP T Switched over to LRS and pumped 8,693.0 8,693.0 00:45 01:45 200 Bbls Isotherm 3 BPM 1200 PSI. SIP 700 PSI. 11/16/2016 11/16/2016 0.25 INTRMI CEMENT HOSO T Slacked off and landed casing while 8,693.0 8,703.0 01:45 02:00 bleeding off annulus. 11/16/2016 11/16/2016 - 2.00 INTRM1 CEMENT RURD T Evacuate Isotherm from Stack and 8,703.0 8,703.0 02:00 04:00 drained and laid down Landing Jt. 11/16/2016 11/16/2016 3.00 INTRMI CEMENT -WWSP T Set Packoff and filled void per 8,703.0 8,703.0 04:00 07:00 Cameron Rep. 11/16/2016 11/16/2016 0.50 INTRM1 CEMENT WWSP T Tested Packoff to 5,000 PSI for 10 8,703.0 0.0 07:00 07:30 Min Wittnessed by CPAI Rep. 11/16/2016 11/16/2016 3.00 INTRM1 CEMENT PRTS T Pressured Annulus to 2,000 PSI for 30 0.0 0.0 07:30 10:30 Min.Chart and Gauge were not reading the same.Repeated the Test 2,000 PSI for 30 Min.Test was done pumping Isotherm.Bled off and left 150 PSI on the OA. 11/16/2016 11/16/2016 0.50 INTRMI CEMENT RURD T Rigged down and blew down test 0.0 0.0 10:30 11:00 equiment. 11/16/2016 11/16/2016 1.00 INTRM1 CEMENT BOPE ' T Changed Top Rams from 7 5/8"to 3.5 0.0 0.0 11:00 12:00 to 6"VBR. 11/16/2016 11/16/2016 1.50 INTRM1 WHDBOP RURD T Set Test Plug with 4"Test Jt and filled 0.0 0.0 12:00 13:30 Stack with water.Body tested to 3500 PSI Page 23/55 Report Printed: 12/28/2016 • 1114 Operations Summary (with Timelog Depths) s, 2S-13 ConocoPh cl Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/16/2016 11/16/2016 4.50 INTRM1 WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 13:30 18:00 Brian Bixby.Tested with 4"and 4.5" test joints.250/3500 psi,charted for 5 minutes each. Test#1 Blind rams,CV#12,13 and 14,Kill mud manifolds and 4-1/2"Dart Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and 4-1/2"IF Floor valve. Test#3- CV#8,#10 and HCR Kill, Test#4-CV#6,#7 and Manual kill Test#5- Super Choke& Manual operated choke to 2000 PSI. Test#6-CV#2,#5&Annular Test#7-Upper pipe rams,CV#3,4,6 and 1. Test#8-HCR Choke Test#9-Manual choke and Upper IBOP Test#10-Lower pipe rams and lower IBOP Perform Koomey draw down test. Observed initial system pressure at 3000 psi,after closure 1650 psi,200 psi increase in 8 seconds,and full pressures at 51 seconds. 11/16/2016 11/16/2016 1.00 INTRM1 WHDBOP RURD T Pulled and Laid down test plug and 0.0 0.0 18:00 19:00 test Jt.Installed Long Wearbushing with 12.5"ID. 11/16/2016 11/16/2016 0.50 INTRMI CEMENT RURD T Cleared off and cleaned Rig Floor. 0.0 0.0 19:00 19:30 11/16/2016 11/16/2016 4.00 INTRM1 CEMENT PULD T PU and stood back in Derreck 60 Jts 0.0 0.0 19:30 23:30 (20 Stands)of 4"HWDP.Then PU and stood back in Derreck 30 Jts(10 Stands)of 4"DP. 11/16/2016 11/17/2016 0.50 INTRM1 CEMENT BHAH T PU BHA per Slumberger Reps to 21' 0.0 21.0 23:30 00:00 11/17/2016 11/17/2016 1.75 INTRM1 CEMENT BHAH T Finish PU BHA per Schlumberger to 21.0 367.0 00:00 01:45 367". 11/17/2016 11/17/2016 1.75 INTRM1 CEMENT PULD T RIH with BHA single in DP from the 367.0 1,784.0 01:45 03:30 Pipeshed from 367'to 1,784'.UW 76K DW 72K.Filled pipe every 20 stands. 11/17/2016 11/17/2016 0.50 INTRM1 CEMENT SVRG T Serviced Rig. 1,784.0 1,784.0 03:30 04:00 11/17/2016 11/17/2016 0.50 INTRM1 CEMENT DHEA T Shallow tested MWD. 1,784.0 1,784.0 04:00 04:30 11/17/2016 11/17/2016 8.25 INTRM1 CEMENT PULD T RIH with BHA single in DP from the 1,784.0 8,512.0 04:30 12:45 Pipeshed from 1,784'to 8,512'.UW 180K DW 102K.Filled pipe every 20 stands. 11/17/2016 11/17/2016 7.00 INTRM1 CEMENT QEVL T RIH 8,500'to 10,218'Logging with 8,512.0 10,218.0 12:45 19:45 MWD/LWD @ 450 FPH.UW 196K DW 100K.230 GPM ICP 1,570 psi FCP 1,718 psi. Page 24/55 Report Printed: 12/28/2016 erations Summa with Timelog OprY � Depths) k,�� r; �4 "'`£' 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/17/2016 11/17/2016 2.00 INTRM1 CEMENT CIRC T Circulated and conditioned Mud for 10,218.0 10,218.0 19:45 21:45 Casing Test.Reduced MW from 10.7 PPG to 10.5 PPG.40 RPM Tq 11K 230 GPM 1767 psi.Recip full stand. UW 214K DW 102K RtW 129K Total Stk pumped 6090. 11/17/2016 11/17/2016 1.25 INTRM1 CEMENT PRTS T RU and Tested Casing 3,650 psi for 10,218.0 10,218.0 21:45 23:00 30 Min on chart.RD test hose. 11/17/2016 11/18/2016 1.00 INTRM1 CEMENT COCF T Cleaned out down from 10,218' to 10,218.0 10,279.0 23:00 00:00 Landing collar @ 10,276'.Drilled LC and cement down to 10,279'.GPM 230,PP 1730 psi,RPM 40,Tq 11K, UW 214K,DW 101K,RTW 132K WOB 8-10K.Tagged Cement and Plug @ 10,266'. 11/18/2016 11/18/2016 3.25 INTRM1 CEMENT DRLG T Continue to Clean out Shoetrack and 10,279.0 10,414.0 00:00 03:15 Rathole.From 10,279'to 10,414'.FC and Shoe came in 5'low.FC @ 10,360'and Shoe @ 10,406'.230 GPM, 1825 psi,5-10K WOB,60 RPM. 11/18/2016 11/18/2016 0.50 INTRM1 CEMENT DDRL T Directional Drilled from 10,414'to 10,414.0 10,434.0 03:15 03:45 10434'MD,6,360'TVD,GPM 230,PP 1905 PSI,RPM 60,TQ on Btm 11.5K, WOB 5 to 10K,UW 174K,DW 104K, RW 133K,ECD 11i,ADT.40 Hrs 11/18/2016 11/18/2016 1.00 INTRM1 CEMENT CIRC T Circulated and conditioned Mud for 10,434.0 10,434.0 03:45 04:45 Casing Test.MW 10.5 PPG.60 RPM Tq 11K 230 GPM 1914 psi.Recip full stand.UW 177K DW 105K RtW 133K Total Stk pumped 3265. 11/18/2016 11/18/2016 0.75 INTRM1 CEMENT FIT T Pulled into casing shoe @ 10,406'. 10,434.0 10,404.0 04:45 05:30 Did FIT to 13.5 PPG EMW. 11/18/2016 11/18/2016 1.50 PROD1 DRILL MPDA T Pulled Flow Nipple and Installed RCD 10,404.0 10,404.0 05:30 07:00 Bearing and Nipple.Calibrated MPD Chokes. 11/18/2016 11/18/2016 1.75 PROD1 DRILL DISP T Pumped 20 Bbl Spacer.Displaced 10,404.0 10,404.0 07:00 08:45well to 9.8 PPG FloPro system.230 GPM, 1930 psi,60 RPM,8 to 9K Tq. UW 174K DW 104K RW 133K.Total Stks 4805.Took SPR. 11/18/2016 11/18/2016 0.75 PROD1 DRILL OWFF T Took SPR through MPD Choke.Did 10,404.0 10,404.0 08:45 09:30 Drawdown test with MPD Choke. 11/18/2016 11/18/2016 1.00 PROD1 -DRILL CIRC T Circulated and conditioned Mud MW 10,404.0 10,404.0 09:30 10:30 9.8 PPG.60 RPM Tq 11K 230 GPM 1874 psi.Recip full stand.UW 177K DW 105K RtW 133K Total Stk pumped 3300.MPD BP 15 psi 11/18/2016 11/18/2016 0.50 PROD1 DRILL SVRG T Serviced Rig. 10,404.0 10,404.0 10:30 11:00 11/18/2016 11/18/2016 0.25 PROD1 DRILL REAM T Circulated and Washed from 10404'to 10,404.0 10,434.0 11:00 11:15 10434'. MW 9.8 PPG.60 RPM Tq 11K 230 GPM 1874 psi. UW 177K DW 105K RtW 133K 11/18/2016 11/18/2016 6.75 PROD1 DRILL DDRL T Directional Drilled from 10,434'to 10,434.0 10,879.0 11:15 18:00 10879'MD,6,340'TVD,GPM 263,PP 2310 PSI,RPM 150,TQ on Btm 11.5K, WOB 15K,UW 177K,DW 101K,RW 130K,ECD 10.97,ADT 4.52 Hrs Max Gas 190 units.MPD BP 15 psi. Page 25/55 Report Printed: 12/28/2016 ink n0 k : " .... Summary (with Timelogipths) 2S-13 ConocoPhiilips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 10,879'to 10,879.0 11,542.0 18:00 00:00 11,542'MD,6,315'TVD,GPM 271, PP 2435 PSI,RPM 150,TQ on Btm 11.5K,WOB 7K,UW 173K,DW 98K, RW 130K,ECD 11.27,ADT 4.01 Hrs Max Gas 209 units MPD BP 15 psi. 11/19/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 11,542'to 11,542.0 12,207.0 00:00 06:00 12,207'MD,6,312'TVD,GPM 272, PP 2460 PSI,RPM 150,TQ on Btm 11.5K,WOB 13K to 15K,UW 177K, DW 100K,RW 128K,ECD 11.21,ADT 4.17 Hrs Max Gas 140 units MPD BP 15 psi. 11/19/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 12,207'to 12,207.0 13,154.0 06:00 12:00 13,154'MD,6,290'TVD,GPM 272, PP 2530 PSI,RPM 150,TQ on Btm 15K,WOB 15K to 16K,UW 195K,DW 90K,RW 132K,ECD 11.36,ADT 3.94 Hrs Max Gas 120 units MPD BP 15 psi. 11/19/2016 11/19/2016 4.75 PROD1 DRILL DDRL T Directional Drilled from 13,154'to 13,154.0 13,912.0 12:00 16:45 13,912'MD,6,272'TVD,GPM 272, PP 2695 PSI,RPM 160,TQ on Btm 15K,WOB 15K to 16K,UW 189K,DW 86K,RW 132K,ECD 11.45,ADT 2.93 Hrs Max Gas 286 units MPD BP 15 psi. 11/19/2016 11/19/2016 0.50 PROD1 DRILL SVRG T Serviced Rig. 13,912.0 13,912.0 16:45 17:15 11/19/2016 11/19/2016 0.50 PROD1 DRILL RGRP T Changed seal in Union on HP Mud 13,912.0 13,912.0 17:15 17:45Hose between the Pump Module and Rig. 11/19/2016 11/19/2016 2.75 PROD1 DRILL DDRL T Directional Drilled from 13,912'to 13,912.0 14,100.0 17:45 20:30 14,100'MD,6,276'TVD,GPM 272, PP 2540 PSI,RPM 160,TQ on Btm 16K,WOB 15K to 14.5K,UW 189K, DW 86K,RW 132K,ECD 11.45,ADT 2.93 Hrs Max Gas 0 units MPD BP 15 psi. 11/19/2016 11/19/2016 1.00 PROD1 DRILL MPDA T Changed RCD Bearing.Maintained 14,100.0 14,100.0 20:30 21:30 150 PSI with Bag.Warmed up bearing. 11/19/2016 11/20/2016 2.50 PROD1 DRILL DDRL T Directional Drilled from 14,100'to 14,100.0 14,384.0 21:30 00:00 14,384'MD,6,294'TVD,GPM 272, PP 2690 PSI,RPM 160,TQ on Btm 15K,WOB 14.5K,UW 193K,DW 86K, RW 132K,ECD 10.91,ADT 1.56 Hrs Max Gas 253 units MPD BP 15 psi. 11/20/2016 11/20/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 14,384'to 14,384.0 15,237.0 00:00 06:00 15,237'MD,6,298'TVD,GPM 272, PP 2675 PSI,RPM 160,TQ on Btm 15.5K,WOB 15.5K,UW 207K,DW 68K, RW 127K,ECD 11.52,ADT 4.22 Hrs Max Gas 225 units MPD BP 15 psi. 11/20/2016 11/20/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 15,237'to 15,237.0 15,978.0 06:00 12:00 15,978'MD,6,298'TVD,GPM 272, - PP 2865 PSI,RPM 160,TQ on Btm 15K,WOB 14K,UW 206K,DW 82K, RW 129K,ECD 11.61,ADT 3.31 Hrs Max Gas 240 units MPD BP 15 psi. Page 26/55 Report Printed: 12/28/2016 EX 0 terations Summary (with Timelogtpths) 2S-13 +Cortoc°Phillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/20/2016 11/20/2016 8.25 PROD1 DRILL DDRL T Directional Drilled from 15,978'to 15,978.0 16,917.0 12:00 20:15 16,917'MD,6,250'TVD,GPM 272, PP 3165 PSI,RPM 160,TQ on Btm 15K,WOB 14.5 to 6.5K,UW 220K, DW 84K,RW 145K,ECD 11.71,ADT 6.03 Hrs Max Gas 204 units MPD BP 15 psi. 11/20/2016 11/20/2016 1.25 PROD1 CASING CIRC T CBU 279 GPM 3120 psi, 160 RPM, 16,917.0 16,917.0 20:15 21:30 13K Tq, 11.54 ECD,Max Gas 120 • units,RW 137K 11/20/2016 11/20/2016 1.00 PROD1 CASING OWFF T Did Drawdown test w MPD.Build up 16,917.0 16,917.0 21:30 22:30 pressuer declined each cycle indicating Well Bore Breathing. 11/20/2016 11/21/2016 1.50 PROD1 CASING OWFF T OWFF to confirm Breathing. 16,917.0 16,917.0 22:30 00:00 11/21/2016 11/21/2016 1.00 PROD1 CASING OWFF T OWFF to confirm Breathing.Breathing 16,917.0 16,917.0 00:00 01:00 confirmed. 11/21/2016 11/21/2016 0.25 PROD1 CASING PULD T Lay down single and drop rabbit. 16,917.0 16,888.0 01:00 01:15 11/21/2016 11/21/2016 7.25 PROD1 CASING BKRM T Back Reamed from 16,888'to 14,767' 16,888.0 14,767.0 01:15 08:30 GPM 272 PP 2650 psi,RPM 150 with Tq 11-13K ECD 11.51,Max Gas 711 units. 11/21/2016 11/21/2016 6.50 PROD1 CASING REAM T' Well packed off @ 14,767'.Worked 14,767.0 14,873.0 08:30 15:00 Tight Spots 14,861'establishing pump and rotation.Stood back one stand and PU a single to have room to work. Established circulation and rotation at 14,873'.Recipicated and rotated while staging pump up to 5 BPM with 1920 psi,140 RPM with 12K Tq,ECD 11.17.Laid down single. 11/21/2016 11/21/2016 1.50 PROD1 CASING BKRM T Backreamed from 14,873'to 14,665' 14,873.0 14,665.0 15:00 16:30 Worked pump up to 6 BPM 2440 psi, 140 RPM 12K Tq,Continue to adjust pump rate for packoff. 11/21/2016 11/21/2016 1.00 PROD1 CASING SMPD T RIH from 14,665'to 15,046'to check 14,665.0 15,046.0 16:30 17:30 hole condition.DW 60 to 75K. 11/21/2016 11/21/2016 1.50 PROD1 CASING SMPD T POOH from 15,046'to 14,665'Strip 15,046.0 14,665.0 17:30 19:00 out with 175 psi BP.UW 209K. 11/21/2016 11/22/2016 5.00 PROD1 CASING BKRM T Backreamed from 14,665'to 13,915' 14,665.0 13,903.3 19:00 00:00 GPM 254 2375 psi,140 RPM 14.3K Tq,Started @ 250 FPH and increased to 500 FPH.Minor packoff @ 14,880'. 11/22/2016 11/22/2016 6.00 PROD1 CASING BKRM T Backream OOH f/13915'-12210'w/ 13,903.3 12,198.3 00:00 06:00 265 gpm,2320 psi,9%F/O, 11.16 ECD, 140 rpm,10-12k Tq,pulling at 700 ft/hr as hole conditions allow. 11/22/2016 11/22/2016 5.25 PROD1 CASING BKRM T Backream OOH f/12210'-11504'w/ 12,198.3 11,492.3 06:00 11:15 265 gpm,2155 psi,9%F/O, 11.01 ECD, 140 rpm,8-10k Tq,pulling at 700 ft/hr as hole conditions allow. Page 27/55 Report Printed: 12/28/2016 0o a-'---,t.. !perations Summary (with Timelog C7epths) 2S-13 ConocoPhillips , Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/22/2016 11/22/2016 0.75 PROD1 CASING PMPO T Pump OOH f/11504'-10414'w/265 11,492.3 10,488.3 11:15 12:00 gpm,2090 psi,9%F/O.Observe pressure increase to 2400 psi at 10414'MD.RIH to 10420',bleed off pressure,and pull up into shoe to 10402'w/no pumps,PUW 177k. Establish rate inside casing w/265 gpm,2125 psi, 10%F/O, 100 rpm,8- 9k Tq.Kill pumps and rotary and trip in hole to 10500'. 11/22/2016 11/22/2016 1.00 PROD1 CASING REAM T Attempt to pull back into shoe w/200 10,488.3 10,392.3 12:00 13:00 gpm, 1375 psi-observe pack off w/bit at the 7-5/8"shoe.Kill pump and drop down below shoe.Pull bit inside shoe, observing slight overpull,and stage up pumps to 3.5 bpm.Observe hole start to pack off at 3.5 bpm,drop rate to 3 bpm,787 psi,and stage up rotary to 80 rpm,7k Tq,ROT 133k and ream through shoe.Kill pumps and rotary and trip through shoe,no issues,PUW 173k,SOW 112k. 11/22/2016 11/22/2016 3.25 PROD1 CASING DISP T Circulate cased hole to Kill weight Flo- 10,392.3 10,392.3 13:00 16:15 Pro.Pump 30 bbl low-vis sweep followed by 30 bbl hi-vis sweep. Continue circulating and weighting up system from 9.8ppg to 10.0ppg Flo- Pro,total 940 bbls pumped. 11/22/2016 11/22/2016 0.75 PROD1 CASING OWFF T Perform MPD drawdown,observing 10,392.3 10,392.3 16:15 17:00 pressure drop f/58 psi to 28 psi on continuous decreasing trend, indiciating slight breathing-well deemed static. 11/22/2016 11/22/2016 2.50 PROD1 CASING SLPC T Slip/cut 117'drill line and calibrate 10,392.3 10,392.3 17:00 19:30 top drive/amphion system. SIMOPS-Continue to OWFF observing flow decrease to static. Open up MPD chokes and inspect- large amount of aluminum and rubber found in choke#1 11/22/2016 11/23/2016 4.50 PROD1 CASING BKRM T Backream OOH f/10404'-8700'w/ 10,392.3 8,688.3 19:30 00:00 200 gpm, 1300 psi,7%F/O 10.61 ECD,50 rpm,7k Tq,ROT 130k. Note:Unable to strip OOH due to floats not holding OA pressure=1050 psi 11/23/2016 11/23/2016 6.00 PROD1 CASING BKRM T Backream OOH f/8700'-5667'w/200 8,688.3 5,655.3 00:00 06:00 gpm, 1100 psi,8%F/O,50 rpm,6.5k Tq,ROT 119k. Note:2.38"rabbit was stuck in stand #74.Racked by itself on drillers side and re-drifted stand#75 to confirm it was ok. Page 28/55 Report Printed: 12/28/2016 !peratlons Summary (with Timelog 17epths) ,. 2S-13 ConocoPhillips R.I.r ka Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/23/2016 11/23/2016 6.00 PROD1 CASING BKRM , T Backream OOH f/5667'-2546'w/200 5,655.3 2,534.3 06:00 12:00 gpm,865 psi,8%F/O,50 rpm,2k Tq, ROT 79k. Note:2.38"rabbit was stuck in stand #45.Racked by itself on drillers side. Found rabbit stuck again in stand#41. Removed 2.38"rabbit and dropped 1.9"(1 29/32")rabbit from stand#41 onwards. 11/23/2016 11/23/2016 1.50 PROD1 CASING CIRC T Circulate/condition hole clean, 2,534.3 2,534.3 12:00 13:30 pumping 25 bbl hi-vis sweep followed with 10.0ppg Flo-Pro at 241 gpm, 1152 psi, 11%F/O,50 rpm, 1.5k Tq, / 10.87 ppg ECD. Note:Observed large amount of cuttings coming over shakers after first bottoms up. 11/23/2016 11/23/2016 4.00 PROD1 CASING PMPO T Pumped OOH to top of HWDP f/2546' 2,534.3 355.3 13:30 17:30 -367'w/240 gpm,1120 psi,7%F/O. 11/23/2016 11/23/2016 1.00 PROD1 CASING CIRC T Pumped hi-vis sweep and chased with 355.3 355.3 17:30 18:30 10.0ppg Flo-Pro w/240 gpm,940 psi, 12%F/O,50 rpm, 1k Tq. Note:Observed metal shavings coming over the shakers at bottoms up,large majority being aluminum and small portion being steel. 11/23/2016 11/23/2016 0.25 PROD1 CASING OWFF T Monitor well for flow-static.Blow 355.3 355.3 18:30 18:45 down top drive. 11/23/2016 11/23/2016 1.50 PROD1 CASING MPDA T Pull MPD bearing assembly and drain 355.3 355.3 18:45 20:15 nipple. Install trip nipple.Clean/clear rig floor. 11/23/2016 11/23/2016 2.25 PROD1 CASING BHAH T Pull OOH racking back HWDP and 355.3 -11.8 20:15 22:30 jars and laying down BHA.Observed both flapper and plunger floats plugged open with debris.Bit graded 3 -2-BT-N-X-2-CT-TD. i SIMOPS-Blow down MPD lines. 11/23/2016 11/23/2016 0.50 PROD1 CASING .BHAH T Clean/clear rig floor -11.8 -11.8 22:30 23:00 11/23/2016 11/24/2016 1.00 COMPZ1 CASING -RURD T Rig up to run 4-1/2"liner. -11.8 -11.8 23:00 00:00 OA pressure=360 psi 11/24/2016 11/24/2016 1.00 COMPZI CASING RURD T Rig up to run liner,change out -11.8 -11.8 00:00 01:00 elevators and rig up power tongs. Confirm pipe count in shed. 11/24/2016 11/24/2016 0.25 COMPZI CASING SFTY T Hold PJSM for running 4-1/2"liner. -11.8 -11.8 01:00 01:15 11/24/2016 11/24/2016 4.75 COMPZI CASING PUTB T Run 4-1/2"12.6#L-80 IBT-m liner as -11.8 2,369.3 01:15 06:00 per tally to 2381',allowing liner to self- fill and monitoring displacement on pit #5. 11/24/2016 11/24/2016 6.00 COMPZ1 CASING PUTB T Run 4-1/2"12.6#L-80 IBT-m liner as 2,369.3 5,763.3 06:00 12:00 per tally f/2381'-5775',allowing liner to self-fill and monitoring displacement on pit#5.PUW 95k,SOW 82k. Page 29/55 Report Printed: 12/28/2016 Iterations Summary (with Timelogtpths) 1.0 02,} 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/24/2016 11/24/2016 1.75 COMPZ1 CASING PUTB T Run 4-1/2"12.6#L-80 IBT-m liner as 5,763.3 6,593.3 12:00 13:45 per tally f/5775'-6605',allowing liner to self-fill and monitoring displacement on pit#5.SOW 85k. 11/24/2016 11/24/2016 2.25 COMPZ1 CASING OTHR T Make up sealbore extension,Liner 6,593.3 6,763.3 13:45 16:00 hanger/packer assembly,and running tool. Fill liner sleeve with Pal mix.Make up float sub w/flapper-style float,XO,and 1 x stand 4"DP to 6775'. 11/24/2016 11/24/2016 0.25 COMPZI CASING CIRC T Stage up pumps to 2 bpm, 100 psi 6,763.3 6,763.3 16:00 16:15 and confirm circulation.Blow down top drive.PUW 105k,SOW 88k. 11/24/2016 11/24/2016 3.25 COMPZ1 CASING RUNL T Run liner in on 4"DP stands f/6775'- 6,763.3 10,363.3 16:15 19:30 10375'just above shoe,filling pipe on the fly and topping off every 5 x stands with fill-up hose,monitoring displacement on pit#5.SOW 105k. Note:Rabbited stand 45&74 from derrick w/2"OD drift 11/24/2016 11/24/2016 0.75 COMPZ1 CASING CIRC T Stage up to 5 bpm,528 psi,8%F/O 10,363.3 10,363.3 19:30 20:15 and circulate 1 x DP volume.Drop rate to 3 bpm,312 psi,5%F/O and rotate string at 30 rpm,7k tq,ROT 124k.Kill pump/rotary,work torque out,and obtain PUW 145k,SOW 107k.Total 45 bbls pumped.Blow down top drive.Cased hole FF=0.15 11/24/2016 11/25/2016 3.75 COMPZ1 CASING RUNL T Run liner in on 4"DP stands f/10375' 10,363.3 13,678.3 20:15 00:00 -13690',filling pipe on the fly and topping off every 5 x stands with fill-up hose,monitoring displacement on pit i #5.Observe open hole FF increase to 0.25-0.30. OA pressure=100 psi 11/25/2016 11/25/2016 6.75 COMPZ1 CASING RUNL T Run liner in on total of 88 x 4"DP 13,678.3 16,854.3 00:00 06:45 stands and 20 x 4"HWDP stands f/ 13690'-16866',filling pipe on the fly and topping off every 5 x stands with fill-up hose,monitoring displacement on pit#5.PUW 200k,SOW 80k.Make up 5'spaceout pup on top of HWDP. Note:Rabbited HWDP stands 19&20 from derrick w/2"OD drift 11/25/2016 11/25/2016 1.00 COMPZI CASING RUNL T RIH to 16905'and obtain parameters, 16,854.3 16,893.3 06:45 07:45 PUW 200k,SOW 80k.Stage up pumps to 5 bpm,1055 psi,8%F/O and circulate 1 x DP volume. Page 30/55 Report Printed: 12/28/2016 ot tperations Summary (with Timelogltpths) tz 2S-13 coPhilliips Alaska Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2016 11/25/2016 1.25 COMPZ1 CASING PACK T Drop 1.5"phenolic ball and pump 16,893.3 16,893.3 07:45 09:00 down @ 3 bpm,650 psi,6%F/O, reducing to 2 bpm,490 psi,5%F/O after 470 strokes.Ball on seat @ 770 strokes.Pressure up to 2500 psi and slack off to block weight to set hanger. Pressure up to 3500 psi to release from hanger and observe pressure falling off and flow returns at surface. Pick up to 200k and confirm not released yet.Slack off to block weight and pressure up to 2500 psi, observing pressure fall off and flow returns at surface.Pick up to 208k and confirm not released yet. 11/25/2016 11/25/2016 1.00 COMPZ1 CASING PACK T Drop 2nd 1.5"ball and pump down at 16,893.3 16,893.3 09:00 10:00 3 bpm,ICP 1215 psi,FCP 970 psi,7% F/0,reducing to 2.5 bpm,780 psi,6% F/O after 700 strokes.Total of 1002 strokes pumped,no pressure increase observed to indicate ball seated. 11/25/2016 11/25/2016 1.50 COMPZ1 CASING PACK T Work down left-hand torque and 16,893.3 16,893.3 10:00 11:30 perform left-hand release from liner as per Baker rep.Pick up and release dogs,PUW 175k,SOW 135k. 11/25/2016 11/25/2016 0.50 COMPZ1 CASING PACK T Set liner top packer as per Baker w/ 16,893.3 10,220.3 11:30 12:00 30rpm, 10k Tq,slacking off to block weight to confirm set.PUW 175k, SOW 135k. Liner top packer set at 10,232.11'MD. 11/25/2016 11/25/2016 1.25 COMPZ1 CASING PRTS T Rig up and pressure test liner top 10,220.3 10,220.3 12:00 13:15 packer to 3500 psi,30 min,charted- good test.Blow down lines. 11/25/2016 11/25/2016 0.50 COMPZ1 -WELLPR TRIP T Pull OOH f/10230'-10171',racking 10,220.3 10,159.3 13:15 13:45 back 4"DP stand and laying down 4" pup joint. 11/25/2016 11/25/2016 2.25 COMPZ1 WELLPR CIRC T Circulate/condition mud while 10,159.3 10,159.3 13:45 16:00 reciprocating w/300 gpm, 1290 psi. PUW 184k,SOW 133k.No gas observed at bottoms up but observed 9.8+-9.9 ppg returns.Continue circulating until 10ppg in/out observed. 11/25/2016 11/25/2016 0.50 COMPZ1 WELLPR CRIH T Pump 10 bbls hi-vis spacer followed 10,159.3 10,159.3 16:00 16:30 by 9 bbls Corrosion Inhibited brine, followed by 20 bbls hi-vis spacer. Chase with 10.0ppg mud to spot. 11/25/2016 11/25/2016 1.00 COMPZ1 WELLPR PMPO T Pull up above CI pill f/10171'-10025'. 10,159.3 9,624.3 16:30 17:30Pump OOH laying in hi-vis spacer f/ 10025'-9636'w/2 bpm,375 psi, PUW 178k. 11/25/2016 11/25/2016 1.00 COMPZ1 WELLPR OWFF T Monitor well for flow-observe well 9,624.3 9,624.3 17:30 18:30 breathing back slowly on decreasing trend.Continue to monitor,initial rate of 62 sec/quart decrease to 97 sec/quart. Page 31/55 Report Printed: 12/28/2016 0 !perations Summary (with Timelog i7epths) 2S-13 Co€t%coPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2016 11/25/2016 1.50 COMPZ1 WELLPR TRIP T Pull OOH on elevators f/9636'-8805', 9,624.3 8,793.3 18:30 20:00 racking back 4"HWDP,monitoring displacement on pit#5.pulling speed 15-20 ft/min,PUW 157k,SOW 117k. Observe incorrect hole fill. 11/25/2016 11/25/2016 0.25 COMPZ1 WELLPR OWFF T Monitor well for flow-static. 8,793.3 8,793.3 20:00 20:15 11/25/2016 11/25/2016 2.75 COMPZ1 WELLPR PMPO T Pump OOH f/8805'-7018' w/3.5 8,793.3 7,006.3 20:15 23:00 bpm,415 psi,5%F/O,monitoring displacement on pit#5.PUW 132k. 11/25/2016 11/25/2016 0.25 COMPZ1 WELLPR OWFF T Blowdown topdrive and monitor well 7,006.3 7,006.3 23:00 23:15 for flow-well static. 11/25/2016 11/26/2016 0.75 COMPZ1 WELLPR TRIP T Pull OOH f/7018'-654T,monitoring 7,006.3 6,535.3 23:15 00:00 displacement on pit#5.PUW 124k. 11/26/2016 11/26/2016 0.75 COMPZ1 WELLPR TRIP T Pull OOH f/6547'-6156'at 1080 ft/hr 6,535.3 6,144.3 00:00 00:45 pulling speed,monitoring displacement on pit#5.Observe incorrect hole fill. 11/26/2016 11/26/2016 0.25 COMPZI WELLPR OWFF T Monitor well for flow-static. 6,144.3 6,144.3 00:45 01:00 11/26/2016 11/26/2016 3.00 COMPZ1 WELLPR PMPO T Pump OOH f/6156'-4260'at 4000 6,144.3 4,248.3 01:00 04:00 fUhr pulling speed w/4 bpm,320 psi to offset swab,monitoring displacement on pit#5.Blow down top drive and confirm well static. 11/26/2016 11/26/2016 3.50 COMPZ1 WELLPR TRIP T Pull OOH f/4260'-65 at 3000 ft/hr 4,248.3 53.3 04:00 07:30 pulling speed,monitoring displacement on trip tank. 11/26/2016 11/26/2016 1.00 COMPZ1 WELLPR BHAH T Lay down liner running tools, 53.3 -11.8 07:30 08:30 monitoring displacement on trip tank- observe good indication of shear. Recovered both 1.5"balls.1st ball had signs of washout on it.2nd ball was not damaged. 61.9 bbls calculated displacement. 58.1 bbl actual displacement 11/26/2016 11/26/2016 0.50 COMPZI WELLPR RURD T Clean/clear rig floor. -11.8 -11.8 08:30 09:00 11/26/2016 11/26/2016 1.00 COMPZ1 WHDBOP RURD T Pull wear bushing and install test plug. -11.8 -11.8 09:00 10:00 Rig up test assembly,purge air from BOP stack and choke manifold w/ water,and perform body test. Page 32/55 Report Printed: 12/28/2016 gperations Summary (with Timelogepths) 021.1. 2S-13 ConocoPhillips AiasAs Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2016 11/26/2016 6.25 COMPZ1 WHDBOP BOPE T Tested BOPE with 4"and 4-1/2"test -11.8 -11.8 10:00 16:15 joint.250/3500 psi,charted for 5 minutes each.Witness waived by AOGCC Rep.Louis Grimaldi. Install 4"Test Joint and test: Test#1 -Annular,CV#1,#12,#13, #14,4"kill line valve on mud manifold, and 4"FOSV. Test#2-Upper 3-1/2"x 6"VBR's,CV #9,#11,mezzanine kill valve,and 4" dart valve. Test#3-CV#8,#10,and HCR Kill. Test#4-CV#6,#7,and manual kill. Test#5-Super choke to 1500 psi Test#6-Manual choke to 1500 psi Test#7-CV#2 and#5. Test#8-Lower 3-1/2"x 6"VBR's. Install 4-1/2"Test joint and test: Test#9-Annular,CV#3,#4,and#6 Test#10-Upper 3-1/2"x 6"VBR's, Lower IBOP,and HCR choke. Test#11 -Manual choke and Upper IBOP Test#12-Lower 3-1/2"x 6"VBR's Test#13-Blind rams Perform Koomey draw down test. Observed initial system pressure at ACC-2950 PSI, MAN-1525 PSI. After Closure observed ACC-1800 PSI,200 PSI increase in 7 seconds, full pressure at 49 seconds. Drawdown test performed w/2 electric pumps and 2 x air pumps.Observed 6 nitrogen bottles with an average PSI of 2658 PSI. Tested all gas and PVT alarms,both audio and visual-good tests.Note that the upper IBOP failed initial test- after functioning and greasing once,it re-tested good. 11/26/2016 11/26/2016 0.75 COMPZ1 WHDBOP RURD T Pull test plug,install 12.5"ID wear -11.8 -11.8 16:15 17:00 bushing,and lay down test joint. 11/26/2016 11/26/2016 1.25 PROD2 WHPST -SVRG T Change out saver sub.SIMOPS -11.8 -11.8 17:00 18:15 mobilize whipstock BHA to rig floor. 11/26/2016 11/26/2016 0.50 PROD2 WHPST RURD T Clear rig floor and verify whipstock -11.8 -11.8 18:15 18:45 BHA assembly. 11/26/2016 11/26/2016 0.25 PROD2 WHPST SFTY T Hold PJSM for picking up whipstock -11.8 -11.8 18:45 19:00 assembly. 11/26/2016 11/26/2016 2.00 PROD2 WHPST BHAH T Make up window mill,lower window -11.8 -11.8 19:00 21:00 mill,flex joint,upper string mill,XO,1 xjt 4"HWDP,XO,and Impulse MWD assembly.Scribe MWD assembly as per SLB/Baker and rack back in derrick. Note:Window mill and upper string mill gauged at 6-3/4".Lower window mill gauged at 6-5/8" 11/26/2016 11/26/2016 0.75 PROD2 WHPST BHAH T Make up seal assembly,no-go locater, -11.8 146.3 21:00 21:45 unloader,XO,4 x joints 4"DP,and 2 x pups 4"DP to 158'. Page 33/55 Report Printed: 12/28/2016 "' perations>Yt0 Summary (with Timelo9 pthe ) , 2S-13 ConocoPhiElips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2016 11/26/2016 1.00 PROD2 WHPST BHAH T Make up 7-5/8"Gen 2 Whipstock, 146.3 275.3 21:45 22:45 debris sub,drain sub,safety disconnect,7-5/8"bottom trip anchor, Baker Xtreme Magnet,and XO.RIH to 196'.Pin window mill to whipstock w/ 45k shear bolt and install snap ring. RIH to 287'. Note:Bottom anchor pinned w/6 x 3650 lb shear bolts and transport bolt removed prior to RIH. 11/26/2016 11/27/2016 1.25 PROD2 WHPST BHAH T Make up 2 x float subs w/non-ported 275.3 549.3 22:45 00:00 flapper-style floats,X0,2 x stands 4" HWDP,X0,4 x MI Swaco Magnostar magnets,X0,and 1 x joint 4"DP and RIH to 561'. OA pressure=120 psi. 11/27/2016 11/27/2016 1.25 PROD2 WHPST TRIP T RIH w/7-5/8"whipstock aseembly on 549.3 1,495.3 00:00 01:15 4"DP stands to 1507',monitoring displacement on pit#1. 11/27/2016 11/27/2016 0.25 PROD2 WHPST DHEQ T Shallow test MWD tools w/236 gpm, 1,495.3 1,495.3 01:15 01:30 716 psi,8%F/O-good test.Blow down top drive. 11/27/2016 11/27/2016 8.50 PROD2 WHPST TRIP T RIH w/7-5/8"whipstock assembly on 1,495.3 10,022.3 01:30 10:00 4"DP stands f/1507'-10034', increasing running speed to 60 fUmin, monitoring displacement on pit#1, and filling pipe every 20 x stands, PUW 166k,SOW 110k. 11/27/2016 11/27/2016 1.75 PROD2 WHPST SRVY T Wash down stand#101 f f/ 10,022.3 10,180.3 10:00 11:45 10034'-10192'and orient whipstock to 20°left of high side w/230 gpm, 1317 psi,8%F/O. Note:Laid out top single of stand #102. 11/27/2016 11/27/2016 1.00 PROD2 WHPST SRVY T Wash down stand#103 w/226 gpm, 10,180.3 10,221.3 11:45 12:45 1295 psi,8%F/O and orient whipstock to 23°left of high side.Tag top of liner at 10233.69'w/no-go(bottom of seals at 10237.66').PUW 170k,SOW 110k Note:Top of Liner found 1.58'deeper than calculated. 11/27/2016 11/27/2016 0.25 PROD2 WHPST WPST T Set whipstock as per Baker rep.Set 10,221.3 10,029.3 12:45 13:00 down 19k weight to shear/set bottom anchor. Pull up to 185k to confirm set. Work string to 190k up and 60k down w/pumps on at 226 gpm, 1290 psi. Kill pump and set down 60k weight to shear bolt and release from whipstock. Confirm released with PUW 178k, SOW 113k. Top of window @ 10,041.54'MD Bottom of window @ 10,055.20'MD Page 34/55 Report Printed: 12/28/2016 gperations Summary (with Timelogepths) 2S-13 ConotoPhitlips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/27/2016 11/27/2016 0.75 PROD2 WHPST CUTP T Obtain parameters at 200 gpm, 1135 10,029.3 10,029.3 13:00 13:45 psi,7%F/O,80 rpm,7k Tq,ROT 135k and take SPRs. SPRs@10041'MD 6289'TVD, MW=10.0ppg,13:05 hours MP#1:20 spm=540 psi,30 spm=700 psi. MP#2:20 spm=520 psi,30 spm=670 psi. 11/27/2016 11/27/2016 7.00 PROD2 WHPST MILL T Tag top of whipstock and mill window 10,029.3 10,043.3 13:45 20:45 f/10041.54'-10055.20'w/212 gpm, 1300 psi,7%F/O,80 rpm,8-10k Tq, 1 -2k WOB. 11/27/2016 11/28/2016 3.25 PROD2 WHPST MILL T Continue milling f/10055'-10064'wl 10,043.3 10,052.3 20:45 00:00 212 gpm, 1355 psi,7%F/O,110 rpm, 9.5k Tq, 10k WOB.Pump 23 bbl hi-vis sweep at bottom of window-observe slight increase in fine shavings as sweep came back over shakers. 11/28/2016 11/28/2016 5.50 PROD2 WHPST DDRL T Mill f/10064'-10080'w/212 gpm, 10,052.3 10,068.3 00:00 05:30 1390 psi,7%F/O, 110 rpm,9.5k Tq, 10-11k WOB.Pump 25 bbl hi-vis sweep at bottom-observe slight increase in fine shavings as sweep came back over shakers. 11/28/2016 11/28/2016 0.50 PROD2 WHPST BKRM T Backream slowly through window f/ 10,068.3 9,982.3 05:30 06:00 10080'-10023'w/212 gpm, 1373 psi, 6%F/O, 100 rpm,8k Tq, 10.1 ppg MW in/out. 11/28/2016 11/28/2016 0.75 PROD2 'WHPST TRIP T Kill pumps/rotary and obtain 9,982.3 9,982.3 06:00 06:45 parameters-PUW 161k,SOW 117k. Trip down through window to bottom, seeing 2-3k drag across whipstock. Trip up through window to 10'above whipstock,seeing 1-2k drag across whipstock.Trip back down through window to bottom,seeing 1-2k drag across whipstock.Trip back up through window to 9994',seeing 1-2k drag across whipstock.Rack back stand,and blow down top drive. 11/28/2016 11/28/2016 1.50 PROD2 WHPST LOT T Rig up and perform LOT to 13.4ppg 9,982.3 9,982.3 06:45 08:15 EMW w/10.1ppg Flo-Pro at 6289.5' TVD.2.1 bbls pumped, 1.3 bbls returned.Rig down and blow down lines. 11/28/2016 11/28/2016 0.75 PROD2 WHPST MPDA T Pull trip nipple,install MPD bearing 9,982.3 9,982.3 08:15 09:00 and drain nipple,and line up for stripping OOH.SIMOPS-Make up top single back onto stand#102. 11/28/2016 11/28/2016 7.00 PROD2 WHPST SMPD T Strip OOH f/9994'-8200'at 3000 ft/hr 9,982.3 633.3 09:00 16:00 w/250 psi pulling,50 psi in slips,f/ 8200'-4200'at 5000 ft/hr w/250 psi pulling,50 psi in slips,and f/4200'- 645'at 4000 ft/hr w/175 psi pulling,50 psi in slips.Maintain 200 gpm through MPD system.Monitor displacement on pit#1. Page 35/55 Report Printed: 12/28/2016 !perations Summary (with Timelog Depths) tam 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End Depth(ftKB) 11/28/2016 11/28/2016 0.50 PROD2 WHPST OWFF T Close chokes and monitor for 633.3 633.3 16:00 16:30 pressure buildup-no pressure.Open up and monitor well for flow-static. 11/28/2016 11/28/2016 0.75 PROD2 WHPST MPDA T Pull MPD bearing and drain nipple. 633.3 633.3 16:30 17:15 Install trip nipple. 11/28/2016 11/28/2016 0.50 PROD2 WHPST TRIP T 'Pull OOH f/645'-365',monitoring 633.3 353.3 17:15 17:45 displacement on pit#1. 11/28/2016 11/28/2016 1.75 PROD2 WHPST BHAH -T Pull OOH f/365'-283',cleaning metal 353.3 271.3 17:45 19:30 off magnets and laying down magnet assembly,monitoring displacement on pit#1.Observe each magnet full w/ fine metal shavings to the OD of the pockets. 11/28/2016 11/28/2016 1.25 PROD2 WHPST BHAH T Pull OOH f/283'to surface,laying 271.3 -11.8 19:30 20:45 down milling assembly as per Baker/ SLB. Window mill=6-5/8"(1/8"Under gauge) Lower string mill=6-5/8"(In gauge) Upper string mill=6-3/4"(In gauge) 11/28/2016 11/28/2016 1.75 PROD2 WHPST WWWH T Rig up stack washer w/1 x string -11.8 -11.8 20:45 22:30 magnet,and 4"DP w/pup joint.RIH and jet stack,functioning annular and upper/lower VBR's.Flush stack w/700 gpm, 120 psi, 18%F/O, 15 rpm.Pull OOH,clean metal off magnets (observed small amount of metal on magnet),and lay out assembly. 11/28/2016 11/28/2016 0.50 PROD2 WHPST RURD T Clean/clear rig floor. -11.8 -11.8 22:30 23:00 11/28/2016 11/28/2016 0.25 PROD2 WHPST SFTY T Hold PJSM for picking up motor BHA. -11.8 -11.8 23:00 23:15 11/28/2016 11/29/2016 0.75 PROD2 WHPST BHAH T Make up BHA#12 as per SLB w/1.5° -11.8 -11.8 23:15 00:00 motor. 11/29/2016 11/29/2016 1.00 PROD2 WHPST BHAH T Finish making up BHA#12 as per SLB -11.8 324.3 00:00 01:00 to 336',monitoring displacement on pit #1. 11/29/2016 11/29/2016 1.00 PROD2 WHPST TRIP T Trip in hole on 4"DP stands f/336'- 324.3 1,773.3 01:00 02:00 1785',monitoring displacement on pit #1. 11/29/2016 11/29/2016 0.25 PROD2 WHPST DHEQ T Fill pipe and shallow hole test MWD w/ 1,773.3 1,773.3 02:00 02:15 205 gpm,835 psi,8%F/O-good test. 11/29/2016 11/29/2016 4.75 PROD2 WHPST TRIP T Trip in hole on 4"DP stands f/1785'- 1,773.3 9,873.3 02:15 07:00 9885',filling pipe every 20 x stands, monitoring displacement on pit#1. 11/29/2016 11/29/2016 0.75 PROD2 WHPST MPDA T Pull trip nipple and install MPD 9,873.3 9,873.3 07:00 07:45 bearing and drain nipple. 11/29/2016 11/29/2016 1.00 PROD2 WHPST CIRC T Establish circulation at 205 gpm, 1495 9,873.3 9,968.3 07:45 08:45 psi,8%F/O and orient bit to 23°left of high side f/9885'-9980'. Page 36/55 Report Printed: 12/28/2016 • 0 Operations Summary (with Timelogtpths) ex 2S-13 � ips` Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/29/2016 11/29/2016 0.25 PROD2 WHPST TRIP T Trip in hole slowly across window and 9,968.3 10,054.3 08:45 09:00 into open hole f/9980'-10066', observing 1-2k consistent drag across the slide and in open hole.PUW 163k, SOW 110k. Note:See additional 3-5k drag each time tool joint passes through MPD bearing 11/29/2016 11/29/2016 0.50 PROD2 DRILL REAM T Wash down to through undergauge 10,054.3 10,068.3 09:00 09:30 hole to bottom f/10066'-10080'w/ 243 gpm, 1810 psi,11%F/O. 11/29/2016 11/29/2016 2.50 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10080'-10111' 10,068.3 10,099.3 09:30 12:00 MD w/250 gpm,1841 psi,9%F/O,40 rpm,8.5k Tq,3-5k WOB.Off btm SPP 1750 psi,PUW 162k,SOW 112k, ROT 135k w/8k Tq,AST 1.36,ART 0.08,ADT 1.44,Bit hrs 1.44,Jar hrs 71.45. Note:Displace well to 9.8 ppg Flo-Pro WBM on the fly on first stand. 11/29/2016 11/29/2016 3.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10111'-10181' 10,099.3 10,169.3 12:00 15:00 MD w/230 gpm, 1915 psi,6%F/O,40 rpm,8.5k Tq,5.8k WOB,ECD 10.74,0ff btm SPP 1650 psi,PUW 167k,SOW 116k,ROT 136k w/7.8k Tq,MW 9.8ppg,Max gas 12 units, AST 1.34,ART 0.68,ADT 2.02,Bit hrs 3.46,Jar hrs 73.47. 11/29/2016 11/29/2016 1.00 PROD2 DRILL SVRG T Service top drive. 10,169.3 10,169.3 15:00 16:00 11/29/2016 11/29/2016 2.75 PROD2 DRILL RGRP T Trouble shoot top drive-hydraulic 10,169.3 10,169.3 16:00 18:45 pump failed.Maintain circulation at 2 bpm,520 psi,5%F/O. 11/29/2016 11/29/2016 0.25 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10181'-10186' 10,169.3 10,174.3 18:45 19:00 MD w/228 gpm, 1645 psi,6%F/O, 3.5k WOB, ECD 10.64,0ff btm SPP 1620 psi,PUW 162k,SOW 116k,MW 9.8ppg,AST 0.1,ART 0,ADT.1,Bit hrs 3.56,Jar hrs 73.57. Note:Needed to get stand down deeper to allow for removal of hydraulic pump. 11/29/2016 11/29/2016 1.00 PROD2 DRILL RGRP T Trouble shoot top drive-hydraulic 10,174.3 10,174.3 19:00 20:00 pump failed.Discover that spare hydraulic pump not correct part. Maintain circulation at 2 bpm,520 psi, 5%F/O. 11/29/2016 11/29/2016 0.75 PROD2 DRILL SMPD T Strip OOH f/10181'-9996'w/35 psi 10,169.3 9,984.3 20:00 20:45 in slips, 130 psi pulling,PUW 172k. Pull BHA slowly across window, observing 1-2 k drag. 11/29/2016 11/30/2016 3.25 PROD2 DRILL RGRP T Remove broken hydraulic pump.Prep 9,984.3 9,984.3 20:45 00:00 for installation of new pump while mobilizing parts from deadhorse. Begin installing new pump at change out. OA pressure=150 psi Page 37/55 Report Printed: 12/28/2016 4 • Operations Summary (with Timelog epths) 0 Fl 2S-13 ConocoPhillips At nAe Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/30/2016 11/30/2016 2.25 PROD2 DRILL RGRP T Replace hydraulic pump on top drive, 9,984.3 9,984.3 00:00 02:15 fill reservoir,and calibrate system. 11/30/2016 11/30/2016 0.75 PROD2 DRILL TRIP T Trip in hole through window to bottom 9,984.3 10,174.3 02:15 03:00 f/9996'-10186',seeing 1k drag across window.PUW 164k,SOW 120k. 11/30/2016 11/30/2016 3.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10186'-10250' 10,174.3 10,238.3 03:00 06:00 MD w/240 gpm, 1800 psi,9%F/O,40 rpm,8.5k Tq,3-8k WOB,ECD 10.89,0ff btm SPP 1750 psi,PUW 165k,SOW 120k,ROT 135k w/8k Tq, MW 9.8ppg,Max gas 349 units,AST 1.46,ART 0.33,ADT 1.79,Bit hrs 5.23,Jar hrs 75.24. 11/30/2016 11/30/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10250'-10435' 10,238.3 10,423.3 06:00 12:00 MD w/240 gpm,2000 psi,7%F/O,40 rpm,8.5k Tq,3-8k WOB,ECD 11.04, Off btm SPP 1800 psi,PUW 165k, SOW 115k,ROT 135k w/8k Tq,MW 9.95ppg,Max gas 225 units,AST 2.94,ART 0.75,ADT 3.69,Bit hrs 8.92,Jar hrs 78.93. SPRs @ 10275'MD 6353'TVD, MW=9.95 ppg,07:00 hours MP#1:20 spm=540 psi,30 spm=760 psi. MP#2:20 spm=540 psi,30 spm=700 psi. 11/30/2016 11/30/2016 1.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10250'-10490' 10,423.3 10,478.3 12:00 13:00 MD w/247 gpm,2110 psi,8%F/O,40 rpm,8.5k Tq,5.5k WOB,ECD 11.11,0ff btm SPP 1888 psi,PUW 158k,SOW 112k,ROT 136k w/7k Tq, MW 10.0 ppg,Max gas 200 units,AST 0,ART 0.84,ADT 0.84,Bit hrs 9.78, Jar hrs 79.77. SPRs @ 10490'MD 6328'TVD, MW=10.0 ppg, 14:30 hours MP#1:20 spm=500 psi,30 spm=720 psi. MP#2:20 spm=470 psi,30 spm=690 psi. 11/30/2016 11/30/2016 1.75 PROD2 DRILL CIRC T Circulate bottoms up at TD w/247 10,478.3 10,478.3 13:00 14:45 gpm,1920 psi,7%F/O,40 rpm,6.8k Tq,ECD 10.96.Orient drill string to 23°left of high side.Blow down top drive. 11/30/2016 11/30/2016 0.75 PROD2 DRILL OWFF T Close MPD chokes and monitor for 10 10,478.3 10,478.3 14:45 15:30 minutes-no pressure buildup.Open up and monitor well for flow for 30 minutes w/5 rpm,6k tq,ROT 130k- well static 11/30/2016 11/30/2016 1.00 PROD2 DRILL SMPD T Strip OOH f/10490'-9992',holding 10,478.3 9,980.3 15:30 16:30 50 psi in slips and 150 psi pulling,Pull slowly through window,observing no drag.PUW 164k 11/30/2016 11/30/2016 0.50 PROD2 DRILL OWFF T Monitor well for flow-static. 9,980.3 9,980.3 16:30 17:00 Page 38/55 Report Printed: 12/28/2016 k1 !peratlons Summary (with Timelogepths) 2S-13 ConocoPhittips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/30/2016 12/1/2016 7.00 PROD2 DRILL SMPD T Strip OOH f/9992-640',holding 50 9,980.3 608.3 17:00 00:00 psi in slips and 175 psi pulling, increasing running speed to 5000 ft/hr. Monitor displacement on pit#5. OA pressure=325 psi 12/1/2016 12/1/2016 0.50 PROD2 DRILL SMPD T Strip OOH f/620'-336',holding 50 psi 608.3 324.3 00:00 00:30 in slips and 175 psi pulling,monitoring displacement on pit#5. 12/1/2016 12/1/2016 0.25 PROD2 DRILL OWFF T Monitor well for flow-static. 324.3 324.3 00:30 00:45 12/1/2016 12/1/2016 0.75 PROD2 DRILL MPDA T Hold PJSM.Pull MPD bearing and 324.3 324.3 00:45 01:30 drain nipple.Install trip nipple. 12/1/2016 12/1/2016 1.50 PROD2 DRILL BHAH T Hold PJSM.Rack back HWDP,jars, 324.3 -11.8 01:30 03:00 and Flex NMDC's.L/D Impulse, Periscope,mud motor,and bit. Observed each outer cutter chipped on the leading edge.Bit graded 1-3- CT-G-X-2-BT-TD.Spring on the top non-ported flapper valve was broken and the valve stuck in open position. 12/1/2016 12/1/2016 1.50 PROD2 DRILL BHAH T Hold PJSM.Make up BHA#13 as per -11.8 325.3 03:00 04:30 SLB to 337',installing 2 x non-ported flapper valves and 1 x non-ported plunger valve floats for MPD. 12/1/2016 12/1/2016 0.75 PROD2 DRILL TRIP T Trip in hole w/4"DP stands f/337'- 325.3 1,788.3 04:30 05:15 1800',monitoring displacement on pit #5. 12/1/2016 12/1/2016 0.25 PROD2 DRILL DHEQ T Shallow hole test MWD tools w/202 1,788.3 1,788.3 05:15 05:30 gpm,870 psi,8%F/O, 10.77 ppg ECD -good test. 12/1/2016 12/1/2016 1.50 PROD2 DRILL TRIP T Trip in hole w/4"DP stands f/1800'- 1,788.3 5,534.3 05:30 07:00 5536',filling pipe every 20 x stands, monitoring displacement on pit#5. 12/1/2016 12/1/2016 0.50 PROD2 DRILL SVRG T Service rig,grease crown and top 5,534.3 5,534.3 07:00 07:30 drive and adjust top drive hydraulics. 12/1/2016 12/1/2016 2.75 PROD2 DRILL TRIP T Trip in hole w/4"DP stands f/5536'- 5,534.3 9,893.3 07:30 10:15 9905',filling pipe every 20 x stands, monitoring displacement on pit#5. PUW 160k,SOW 114k. 12/1/2016 12/1/2016 0.75 PROD2 DRILL MPDA T Pull trip nipple. Install MPD bearing 9,893.3 9,893.3 10:15 11:00 and drain nipple. 12/1/2016 12/1/2016 0.25 PROD2 DRILL MPDA T Break in new bearing w/149 gpm,932 9,893.3 9,893.3 11:00 11:15 psi,7%F/O,30 rpm w/7k tq,60 rpm w/7.5k tq. 12/1/2016 12/1/2016 1.00 PROD2 DRILL TRIP T Trip in hole w/4"DP stands f/9905'- 9,893.3 10,138.3 11:15 12:15 10150',monitoring displacement on pit #5.PUW 161k,SOW 114k.No drag observed while running BHA through window. Note:Observed 10-15k drag @ 9909'. Pick up and work back through section,continue tripping ahead with no issues. Page 39/55 Report Printed: 12/28/2016 all40 !perations Summary (with Timelog epths) 2S-13 ConocoPhitlips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/1/2016 12/1/2016 0.75 PROD2 DRILL WASH T Wash down f/10150'-10310'w/211 10,138.3 10,298.3 12:15 13:00 gpm, 1590 psi,7%F/O,taking check shot surveys as per SLB,PUW 161k, SOW 114k. Note:Observed 10-15k drag @ 10310'and 200 psi increase in pump pressure. 12/1/2016 12/1/2016 1.25 PROD2 DRILL REAM T Ream down f/10310'-10490'w/211 10,298.3 10,478.3 13:00 14:15 gpm,1640 psi,40 rpm,7.5k Tq,taking check shot surveys as per SLB,ROT 133k. 12/1/2016 12/1/2016 3.75 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10490-10740' 10,478.3 10,728.3 14:15 18:00 MD,6302'TVD,w/240 gpm,2150 psi, 8%F/O,140 rpm, 11k Tq,7.5k WOB, ECD 11.04,Off btm SPP 2170 psi, PUW 164k,SOW 107k,ROT 129k w/ 8.5k Tq,MW 9.8 ppg,Max gas 60 units,ADT 2.71,Bit hrs 2.71,Jar hrs 82.48. Note:Dropped mud weight down to 9.8ppg once on bottom drilling. 12/1/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/10740-11322' 10,728.3 11,310.3 18:00 00:00 MD,6277'TVD,w/260 gpm,2202 psi, 9%F/O,160 rpm, 12k Tq,6k WOB, ECD 11.19,Off btm SPP 2198 psi, PUW 162k,SOW 107k,ROT 133k w/ 9k Tq,MW 9.8 ppg,Max gas 155 units,ADT 4.32,Bit hrs 7.03,Jar hrs 86.80. SPRS @ 11229'MD 6281'TVD, MW=9.80 ppg,23:00 hours MP#1:20 spm=540 psi,30 spm=780 psi. MP#2:20 spm=520 psi,30 spm=740 psi. OA pressure=760 psi 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/11332 to 11798' 11,310.3 11,786.3 00:00 06:00 MD,6242'TVD,w/260 gpm,2202 psi, 9%F/O,160 rpm, 12k Tq,6-10k WOB,ECD 11.19,Off btm SPP 2198 psi, PUW 165k,SOW 105k,ROT 125k w/9k Tq,MW 9.8 ppg,Max gas 289 units,ADT 4.41, Bit hrs 11.44,Jar hrs 91.21. SPRS @ 11698'MD 6276'TVD, MW=9.80 ppg,03:50 hours MP#1:20 spm=550 psi,30 spm=770 psi. MP#2:20 spm=540 psi,30 spm=750 psi. Page 40/55 Report Printed: 12/28/2016 °c.. • • Operations Summary (with Timelog Depths) 6. s 2S-13 ConocoPhitlips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/11798 to 12261' 11,786.3 12,249.3 06:00 12:00 MD,6257'TVD,w/260 gpm,2258 psi, 9%F/O, 160 rpm, 14k Tq,6-10k WOB,ECD 11.31,Off btm SPP 2200 psi,PUW 168k,SOW 102k,ROT 133k w/13k Tq,MW 9.8 ppg,Max gas 150 units,ADT 4.47,Bit hrs 15.91,Jar hrs 95.68. SPRs @ 12175'MD 6277'TVD, MW=9.80 ppg, 10:51 hours MP#1:20 spm=630 psi,30 spm=900 psi. MP#2:20 spm=630 psi,30 spm=830 psi. 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/12261'to 12790' 12,249.3 12,778.3 12:00 18:00 MD,6262'TVD,w/260 gpm,2423 psi, 10%F/O, 140 rpm,14k Tq,6-10k WOB,ECD 11.36,Off btm SPP 2416 psi,PUW 164k,SOW 100k,ROT 133k w/13k Tq,MW 9.8 ppg,Max gas 297 units,ADT 4.16,Bit hrs 20.07,Jar hrs 99.84. SPRs @ 12648'MD 6265'TVD, MW=9.80 ppg, 16:30 hours MP#1:20 spm=680 psi,30 spm=940 psi. MP#2:20 spm=640 psi,30 spm=880 psi. 12/2/2016 12/3/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/12790'to 13503' 12,778.3 13,491.3 18:00 00:00 MD,6247'TVD,w/260 gpm,2461 psi, 10%F/O, 140 rpm, 13k Tq, 12k WOB, ECD 11.45,Off btm SPP 2460 psi, PUW 168k,SOW 99k,ROT 134k w/ 8k Tq,MW 9.8 ppg,Max gas 196 units,ADT 4.04,Bit hrs 24.11,Jar hrs 103.88. SPRs @ 13215'MD 6259'TVD, MW=9.85 ppg,21:45 hours MP#1:20 spm=700 psi,30 spm=960 psi. MP#2:20 spm=680 psi,30 spm=900 psi. OA pressure=1100 psi 12/3/2016 12/3/2016 2.75 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/13503'to 13885' 13,491.3 13,873.3 00:00 02:45 MD,6234'TVD,w/264 gpm,2461 psi, 10%F/O, 160 rpm,13k Tq,6-12k WOB, ECD 11.51,Off btm SPP 2460 psi,PUW 172k,SOW 94k,ROT 128k w/12k Tq,MW 9.8 ppg,Max gas 282 units,ADT 1.65,Bit hrs 25.74,Jar hrs 105.53. SPRs @ 13783'MD 6240'TVD, MW=9.80 ppg,02:02 hours MP#1:20 spm=760 psi,30 spm=1040 psi. MP#2:20 spm=730 psi,30 spm=970 psi. Page 41/55 Report Printed: 12/28/2016 0:i. o „..., o o9•Operations Summary (with Time! ths) 2S-13 Cono Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2016 12/3/2016 1.00 PROD2 DRILL SRVY T Pump out of hole 2 x stands f/13885'- 13,873.3 13,873.3 02:45 03:45 13695'w/262 gpm,2460 psi, 172k PUW.Re-survey @ 13695 due to bad survey.Cycle pumps to obtain survey and wash down 2 x stands to bottom w/262 gpm,2460 psi,94k SOW. 12/3/2016 12/3/2016 2.25 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/13885'to 14077' 13,873.3 14,065.3 03:45 06:00 MD,6227'TVD,w/264 gpm,2500 psi, 10%F/O, 160 rpm, 13k Tq,8-12k WOB,ECD 11.50,Off btm SPP 2460 psi,PUW 172k,SOW 94k,ROT 128k w/8k Tq,MW 9.8 ppg,Max gas 108 units,ADT 1.36,Bit hrs 27.10,Jar hrs 106.89. 12/3/2016 12/3/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/14077'to 14790' 14,065.3 14,778.3 06:00 12:00 MD,6265'TVD,w/264 gpm,2550 psi, 10%F/O, 160 rpm, 14k Tq,8-12k WOB,ECD 11.52,Off btm SPP 2500 psi,PUW 174k,SOW 90k,ROT 133k w/12k Tq,MW 9.8 ppg,Max gas 164 units,ADT 3.99, Bit hrs 31.11,Jar hrs 110.88. SPRs©14353'MD 6228'TVD, MW=9.80 ppg,08:15 hours MP#1:20 spm=740 psi,30 spm=980 psi. MP#2:20 spm=760 psi,30 spm=1000 psi. 12/3/2016 12/3/2016 5.25 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/14790'to 15390' 14,778.3 15,378.3 12:00 17:15 MD,6252'TVD,w/270 gpm,2814 psi, 12%F/O, 160 rpm,14k Tq,8-12k WOB,ECD 11.70,Off btm SPP 2729 psi,PUW 191k,SOW 92k,ROT 138k w/8k Tq,MW 9.8 ppg,Max gas 164 units,ADT 3.51,Bit hrs 34.62,Jar hrs 114.39. SPRs @ 15110'MD 6270'TVD, MW=9.85 ppg,14:45 hours MP#1:20 spm=760 psi,30 spm=1000 psi. MP#2:20 spm=770 psi,30 spm=1020 psi. Start adding in Alpine beads and nut plug fine from 14980'to TD. Increase lube concentration to 2.5%.Observed 46'fault @ 14888'and 10'fault @ 14823'-total of 56'throw down to the north.We dropped out of target zone early to minimize loss of pay on other side of fault. 12/3/2016 12/3/2016 1.75 PROD2 DRILL SRVY T Backream out 2 x stands f/15390'- 15,378.3 15,378.3 17:15 19:00 15202'and work section several times where high dogleg,8.4°,was observed w/260 gpm,2621 psi,9% F/O, 100 rpm,8-10k Tq,ECD 11.53, PUW 174k,SOW 90k,ROT 126k. Ream back down to bottom f/15202'- 15390'. Page 42/55 Report Printed: 12/28/2016 • Aerations Summary (with Timelog Depths)El -to est }` 2S-13 conocophiilips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2016 12/4/2016 5.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/15390'to 15853' 15,378.3 15,841.3 19:00 00:00 MD,6242'TVD,w/262 gpm,2730 psi, 10%F/O, 140 rpm, 11-14k Tq, 10-15k WOB,ECD 11.65,Off btm SPP 2725 psi,PUW 190k,SOW 92k,ROT 136k w/9k Tq,MW 9.8 ppg,Max gas 241 units,ADT 3.46,Bit hrs 38.08,Jar hrs 117.85. Note:Observed hard spot of anchorite formation f/15417'-15524'.Pressure continues to build over connections on closed MPD chokes to 70-150 psi,but always builds slower and levels out to lower pressure after cycling chokes, indicating breathing.The 3 x drill string floats started leaking at—15,000'MD. SPRs @ 15668'MD 6251'TVD, MW=9.80 ppg,22:30 hours MP#1:20 spm=760 psi,30 spm=1000 psi. MP#2:20 spm=760 psi,30 spm=1000 psi. OA pressure=1140 psi 12/4/2016 12/4/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/15853'to 16530' 15,841.3 16,518.3 00:00 06:00 MD,6218'TVD,w/262 gpm,2730 psi, 10%F/O, 140 rpm, 11-14k Tq,8-14k WOB,ECD 11.80,Off btm SPP 2725 psi,PUW 192k,SOW 88k,ROT 138k w/13k Tq,MW 9.8 ppg,Max gas 277 units,ADT 3.64,Bit hrs 41.72,Jar hrs 121.49. SPRs @ 16220'MD 6231'TVD, MW=9.85 ppg,02:45 hours MP#1:20 spm=820 psi,30 spm=1080 psi. MP#2:20 spm=830 psi,30 spm=1080 psi. Note:Observed 1 x fault @ 16395',2' throw down to the south. Page 43/55 Report Printed: 12/28/2016 • Iterations Summary (with Timelog Depths) 2S-13 ConocoPhiilips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/4/2016 12/4/2016 3.50 PROD2 DRILL DDRL T DDrill 6-3/4"hole f/16530'to 16980' 16,518.3 16,968.3 06:00 09:30 MD,6208'TVD,w/262 gpm,3018 psi, 10%F/O,160 rpm, 11-15k Tq,8-15k WOB, ECD 11.85,Off btm SPP 3000 psi,PUW 197k,SOW 88k,ROT 140k w/13k Tq,MW 9.8 ppg,Max gas 522 units,ADT 2.44,Bit hrs 44.16,Jar hrs 123.93. SPRs @ 16771'MD 6213'TVD, MW=9.85 ppg,07:30 hours MP#1:20 spm=800 psi,30 spm=1050 psi. MP#2:20 spm=810 psi,30 spm=1060 psi. Final lube concentration=2.5% Lotorq.Added total of 157 bags of Alpine beads&200 bags of nut plug fine into system from 14900'-TD. Total seepage losses for interval=65 bbls.In target A4 zone for 84%of lateral. 12/4/2016 12/4/2016 2.25 PROD2 CASING CIRC T Pump 23 bbl hi-vis sweep and chase 16,968.3 16,850.3 09:30 11:45 w/9.8 ppg mud,circulate 1 x surface- to-surface volume w/262 gpm,3000 psi,160 rpm, 13k Tq,ROT 142k, racking back one stand f/16908'- 16862'. SPRs @ 16955'MD 6209'TVD, MW=9.85 ppg, 11:38 hours MP#1:20 spm=790 psi,30 spm=1070 psi. MP#2:20 spm=800 psi,30 spm=1090 psi. 12/4/2016 12/4/2016 1.75 PROD2 CASING OWFF T Perform MPD exhale test w/10 rpm, 16,850.3 16,850.3 11:45 13:30 9k Tq,ROT 147k.Cycled chokes and observed pressure buildup on decreasing trend and volume bled back on decreasing trend.Initial shut in pressure of 147 psi decreased to 111 psi with total volume bled back= 5.4 bbls.Confirmed wellbore breathing. 12/4/2016 12/4/2016 4.50 PROD2 CASING BKRM T Backream OOH f/16862'-15207'MD 16,850.3 15,195.3 13:30 18:00 @ 1000 ft/hr pulling speed w/260 gpm,ICP 2800 psi,FCP 2550 psi,9% F/O,ECD 11.42, 150 rpm,10-12k Tq, PUW 197k,SOW 88k,ROT 147k. 12/4/2016 12/4/2016 4.25 PROD2 CASING BKRM T Backream OOH f/15207'-14070'MD 15,195.3 14,058.3 18:00 22:15 @ 350-500 fUhr pulling speed wl 260 gpm, ICP 2550 psi,FCP 2500 psi,9% F/O,ECD 11.39, 100-150 rpm,8-11k Tq,PUW 184k,SOW 95k,ROT 120k. Note:No issues observed pulling BHA through fault. Page 44/55 Report Printed: 12/28/2016 operations Summary (with Timelog Depths) 2S-13 conoccPhitiips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/4/2016 12/5/2016 1.75 PROD2 CASING BKRM T Backream OOH f/14070'-13300'MD 14,058.3 13,288.3 22:15 00:00 ©1000 fUhr pulling speed w/262 gpm,ICP 2500 psi,FCP 2490 psi,9% F/O,ECD 11.35, 100 rpm, 10-12k Tq, PUW 170k,SOW 95k, ROT 120k. OA pressure=1100 psi 12/5/2016 12/5/2016 7.25 PROD2 CASING BKRM T Backream OOH f/13300'-10375'MD 13,288.3 10,363.3 00:00 07:15 @ 1000 ft/hr pulling speed w/262 gpm, ICP 2490 psi,FCP 2178 psi,9% F/O,ECD 11.20, 100-140 rpm,9-11k Tq,ROT 122k. Note:Start weighting up 9.8ppg Flo- Pro to 9.9 ppg @ 11900'MD. 12/5/2016 12/5/2016 1.25 PROD2 CASING PMPO T Pump OOH f/10375'-9987',pulling 10,363.3 9,975.3 07:15 08:30 BHA through window w/179 gpm, 1130 psi,PUW 158k.No drag observed while pulling through window. 12/5/2016 12/5/2016 2.50 PROD2 CASING CIRC T Pump 24 bbl hi-vis sweep followed by 9,975.3 9,975.3 08:30 11:00 733 bbls of mud,weighting up 9.9 ppg Flo-Pro system on the fly to 10.2 ppg in/out,adjusting pump rate from 228 gpm to 200 gpm to maintain ECD no greater than 11.5 ppg,final pump pressure 1586 psi.Rotate @ 60 rpm, 6k Tq,reciprocating stand.Obtain SPR's for new mud: SPRs @ 9899'MD 6267'TVD, MW=10.20 ppg, 11:00 hours MP#1:20 spm=670 psi,30 spm=910 psi. MP#2:20 spm=650 psi,30 spm=870 psi. 12/5/2016 12/5/2016 0.25 PROD2 CASING RURD T Blow down top drive and open up well 9,975.3 9,975.3 11:00 11:15 at RCD to monitor for flow. 12/5/2016 12/5/2016 1.00 PROD2 CASING OWFF T Monitor well for flow at RCD head- 9,975.3 9,975.3 11:15 12:15 well static. 12/5/2016 12/5/2016 1.50 PROD2 CASING MPDA T Pull MPD bearing and drain nipple. 9,975.3 9,975.3 12:15 13:45 Install trip nipple.Clean/clear rig floor of MPD equipment. 12/5/2016 12/5/2016 1.75 PROD2 CASING TRIP T Pull OOH on elevators f/9987'-8576', 9,975.3 8,564.3 13:45 15:30 monitoring displacement on trip tank, PUW 169k,SOW 120k.Observe incorrect hole fill.Monitor well for flow -well static. 12/5/2016 12/5/2016 5.25 PROD2 CASING PMPO T Pump OOH to offset swab f/8576'- 8,564.3 5,266.3 15:30 20:45 5278'w/127 gpm,ICP 837 psi,FCP 648 psi,5%F/O,PUW 147k,SOW 110k,monitoring displacement on pit #5. 12/5/2016 12/5/2016 1.25 PROD2 CASING TRIP T Pull OOH on elevators f/5278'-4448', 5,266.3 4,436.3 20:45 22:00 monitoring displacement on trip tank, PUW 109k,SOW 95k.Observe incorrect hole fill.Monitor well for flow -well static. Page 45/55 Report Printed: 12/28/2016 4tperations Summary (with Timelogtepths) 0 r 2S-13 Conoco!'hifiips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/5/2016 12/5/2016 1.75 PROD2 CASING PMPO T Pump OOH to offset swab f/4448'- 4,436.3 3,360.3 22:00 23:45 3372 w!127 gpm, ICP 630 psi,FCP 551 gpm,5%F/O,PUW 97k,SOW 94k,monitoring displacement on pit #5. 12/5/2016 12/6/2016 0.25 PROD2 CASING TRIP T Pull OOH on elevators f/3372'-3285', 3,360.3 3,273.3 23:45 00:00 PUW 91k,SOW 88k,monitoring displacement on trip tank. OA pressure=550 psi 12/6/2016 12/6/2016 2.75 PROD2 CASING TRIP T Cont to POOH f/3285'MD to 368'MD 3,273.3 314.3 00:00 02:45 on elevators.Calculated displacement=103 bbls Actual displacement=151 bbls. 12/6/2016 12/6/2016 1.75 PROD2 CASING BHAH T UD 4"5 joints HWDP,Jars and SLB 314.3 -11.8 02:45 04:30 tools as per SLB.The seal area on the flapper float looked questionable and debris was found in the spring of the plunger float. Smith MDi516 bit grade=0-0-NO-A-X -NO-TD 12/6/2016 12/6/2016 0.50 PROD2 CASING BHAH T Clean and clear rig floor.UD SLB -11.8 -11.8 04:30 05:00 subs and tools. 12/6/2016 12/6/2016 1.50 COMPZ2 FISH BHAH T Make up whipstock retrieval BHA and -11.8 53.3 05:00 06:30 SLB MWD tools.Orient MWD tool face offset to jet on retrieval hook. Observed 292.5 deg tool face offset. 12/6/2016 12/6/2016 0.75 COMPZ2 FISH TRIP T RIH w/4"DP f/65'MD to 1517'MD. 53.3 1,505.3 06:30 07:15 12/6/2016 12/6/2016 0.25 COMPZ2 FISH DHEQ T Shallow hole test MWD tools @ 215 1,505.3 1,505.3 07:15 07:30 gpm=755 psi,good test. 12/6/2016 12/6/2016 3.50 COMPZ2 FISH TRIP T Cont to RIH w/4"DP f/1517'MD to 1,505.3 8,134.3 07:30 11:00 8146'MD. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH SLPC T Slip and cut drilling line,cut off 130'of 8,134.3 8,134.3 11:00 12:00 drilling line.SIMOPS:remove ice build up in derrick. OA pressure=540 psi. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH SLPC T .Finish Slip and cut drilling line,cut off 8,134.3 8,134.3 12:00 13:00 130'of drilling line. 12/6/2016 12/6/2016 1.25 COMPZ2 FISH TRIP T Cont to RIH w/4"DP f/8,146'MD to 8,134.3 9,975.3 13:00 14:15 9,987'MD. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH WASH T Washed down from 9,987'to 10,057'. 9,975.3 10,045.3 14:15 15:15 211GPM, UW177KDW132K. 12/6/2016 12/6/2016 0.25 COMPZ2 FISH FISH P Located and engaged hook.Jarred 10,045.3 9,971.3 15:15 15:30 whipstock free. 12/6/2016 12/6/2016 1.75 COMPZ2 FISH CIRC P CBU X 2 250 GPM 1857 psi.MW in 9,971.3 9,971.3 15:30 17:15 10.2 PPG MW out 10.1+. 12/6/2016 12/6/2016 0.50 COMPZ2 FISH OWFF P OWFF for 30 Min.Small flow did not 9,971.3 9,971.3 17:15 17:45 die off. 12/6/2016 12/6/2016 1.25 COMPZ2 FISH CIRC P CBU to even out MW.250 GPM 1867 9,971.3 9,971.3 17:45 19:00 psi. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH OWFF P OWFF.Well went Static. 9,971.3 9,971.3 19:00 20:00 12/6/2016 12/7/2016 4.00 COMPZ2 FISH PMPO P Attempted to POOH on Elevators Well 9,971.3 8,221.3 20:00 00:00 was swabing.POOH pumping 2.5 to 3 BPM from 9,983'to 8,233'. 105 GPM 605 psi.UW 170K. Page 46/55 Report Printed: 12/28/2016 operations Summary (with Timeloggepths) " ,s$r 2S-13 sono ttih�`,-,,,i. Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/7/2016 12/7/2016 9.25 COMPZ2 FISH PMPO P POOH w/pump @ 106 gpm=600 psi, 8,221.3 2,993.3 00:00 09:15 reduce pumps to 82 gpm=420 psi f/ 8233'MD to 3005'MD.P/U=143K, S/0=85K. 12/7/2016 12/7/2016 2.75 COMPZ2 FISH TRIP P POOH on elevetors f/3005 MD to 2,993.3 838.3 09:15 12:00 850'MD.Monitor hole fill on trip tank. 12/7/2016 12/7/2016 0.75 COMPZ2 FISH TRIP P Continue POOH on elevetors f/850' 838.3 81.3 12:00 12:45 MD to 93'MD. 12/7/2016 12/7/2016 0.75 COMPZ2 FISH BHAH P Lay down Baker Hook assembly. 81.3 -11.8 12:45 13:30 12/7/2016 12/7/2016 1.50 COMPZ2 FISH PULL P Laid down Baker Whipstock.Junk -11.8 -11.8 13:30 15:00 Catcher was missing. 12/7/2016 12/7/2016 1.50 COMPZ2 FISH RURD .P Cleared and cleaned up Rig Floor. -11.8 -11.8 15:00 16:30 12/7/2016 12/7/2016 1.25 COMPZ2 CASING RURD P RU to run Liner. -11.8 -11.8 16:30 17:45 12/7/2016 12/8/2016 6.25 COMPZ2 CASING PUTB P Ran 4.5"12.6#L-80 TXP Lower -11.8 4,396.3 17:45 00:00 Completion Liner to 4,408'.UW 85K DW 81K. 12/8/2016 12/8/2016 3.75 COMPZ2 CASING PUTB P Cont.to run 4.5"12.6#L-80 TXP 4,396.3 6,880.3 00:00 03:45 Lower Completion Liner f/4408'MD to 6892'MD.P/U 102K,S/0=86K.Ran a total of 168 joints of 4-1/2"TXP w/ zero remakes and zero rejects,2- 5.75"swell packers,1-6.38"swell packer and 78 6-1/2"Hydroforms. 12/8/2016 12/8/2016 1.00 COMPZ2 CASING BHAH P P/U 3-1/8"SLB collar and instal in 6,880.3 6,914.3 03:45 04:45 tubing stump.M/U slim pulse and obtain tool face offset of 74.58deg. M/U to Baker hook hanger and run in the hole to 6926'MD. 12/8/2016 12/8/2016 0.25 COMPZ2 CASING RURD P Change out handling equipment to 4" 6,914.3 6,914.3 04:45 05:00 XT39. 12/8/2016 12/8/2016 3.00 COMPZ2 CASING RUNL P RIH w/4-1/2"TXP liner on 4"DP f/ 6,914.3 9,944.3 05:00 08:00 6926'MD to above window @ 9956' MD.P/U=149L,S/0=104K. 12/8/2016 12/8/2016 2.00 COMPZ2 CASING RUNL P Shallow hole test MWD tools @ 120 9,944.3 10,326.3 08:00 10:00 gpm=628 psi,good. RIH and attempt to side liner into open hole,tagged main bore SBE @ 10,245K.POOH to 10,000'MD,put 1/2 a wrap in drill string and worked down.RIH and tagged @ 10,245'MD.POOH to 10,000'MD,worked 1/4"wrap down. RIH,bent joint passed though window @ 10042'MD.Cont to RIH t/10338' MD.P/U=149K,5/0=104K 12/8/2016 12/8/2016 2.00 COMPZ2 CASING RUNL P Cont RIH w/4-1/2"TXP liner on 4"DP 10,326.3 11,638.3 10:00 12:00 f/10,338'MD to 11,650'MD.P/U= 156K,5/0=100K. 12/8/2016 12/8/2016 6.00 COMPZ2 CASING RUNL P Cont RIH w/4-1/2"TXP liner on 4"DP 11,638.3 16,909.3 12:00 18:00 f/11,650'MD to 16,921'MD.P/U= 210K,5/0=105K. 12/8/2016 12/8/2016 1.00 COMPZ2 CASING SRVY P Estabilished Circulation for MWD. 16,909.3 16,949.3 18:00 19:00 Aligned Tool Face 180 Deg out and worked down hole past Hang off depth to 16,961'MD. Page 47/55 Report Printed: 12/28/2016 operations Summary (with Timelog!epths) 2S-13 ConocoPhillips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/8/2016 12/8/2016 2.00 COMPZ2 CASING HOSO P Attempted to find hook @ 16,957'. 16,949.3 16,947.3 19:00 21:00 Unable to locate hook Reoriented to 180 out and worked through obstruction down to 16,971'. Reoriented and hooked @ 16,959'(2' deep). 12/8/2016 12/8/2016 0.50 COMPZ2 CASING PACK P Dropped 19/32"Ball and pumped 16,947.3 10,063.3 21:00 21:30 down on seat.Released running tool with 3500 psi.Pressured up to 4165 psi to blow ball seat.Confirmed shearout of ball seat. 12/8/2016 12/8/2016 0.50 COMPZ2 WELLPR TRIP P POOH Running Tool from 10,075'to 10,063.3 9,980.3 21:30 22:00 10,035'pumping 1 BPM.Continue POOH to 9,992'.Top of Liner 10,035'. 12/8/2016 12/8/2016 0.25 COMPZ2 WELLPR OWFF P OWFF 10 Min.Static. 9,980.3 9,980.3 22:00 22:15 12/8/2016 12/8/2016 1.50 COMPZ2 WELLPR DISP P Pumped 25 Bbl HV Spacer followed 9,980.3 9,980.3 22:15 23:45 by 10.2 PPG Brine to Surface.269 GPM ICP 1470 psi FCP 1225 psi. 12/8/2016 12/9/2016 0.25 COMPZ2 WELLPR RURD P Blow Down Top Drive. 9,980.3 9,980.3 23:45 00:00 12/9/2016 12/9/2016 1.75 COMPZ2 WELLPR OWFF P OWFF,slight flow.Perform exhale 9,980.3 9,972.3 00:00 01:45 test,Monitor fluid flowing from well w/ vis cup.Initial flow=6.3 seconds per quart and slowed to 9.56 seconds per quart over 1-1/2"hours.P/U=177K. 12/9/2016 12/9/2016 1.50 COMPZ2 WELLPR TRIP P POOH on elevators f/9984'MD to 9,972.3 8,414.3 01:45 03:15 8426'MD.Calculated hole fill 15 bbls, Actual hole fill 13 bbls.Displacement 2 bbls off. 12/9/2016 12/9/2016 0.25 COMPZ2 WELLPR OWFF T OWFF,Monitor fluid discharge w/vis 8,414.3 8,414.3 03:15 03:30 cup and record every 5 min.fluid slowed f/9.06 seconds per quart to 10.75 seconds per quart. 12/9/2016 12/9/2016 0.75 COMPZ2 WELLPR TRIP P POOH on elevators f/8426'MD to 8,414.3 7,464.3 03:30 04:15 7476'MD.Calculated hole fill 5.6 bbls, Actual hole fill 3.6 bbls.Displacement 2 bbls off. 12/9/2016 12/9/2016 1.25 COMPZ2 WELLPR PMPO P POOH w/pump 3 stands f/7476'MD 7,464.3 7,162.3 04:15 05:30 to 7174'MD.Calculated hole fill=1.6 bbls.Actual hole fill=0. 12/9/2016 12/9/2016 1.50 COMPZ2 WELLPR CIRC T Circulate and condition fluid,pump @ 7,162.3 7,162.3 05:30 07:00 200 gpm=380 psi.Observed no gas at bottoms up and circulated to ensure even MW in/out 10.2 ppg. 12/9/2016 12/9/2016 4.75 COMPZ2 WELLPR OWFF T OWFF, Monitor fluid discharge w/vis 7,162.3 7,162.3 07:00 11:45 cup and record every 5 min.Initial reading at 7:05 am was 6 seconds per quart,discharge slowed to 15.75 seconds per quart @ 10:00 am.After 10:00 am this discharged picked up to 6-10 seconds per quart.The decision was made RIH back above hook hanger and increase MW to 10.4+ PPg. 12/9/2016 12/9/2016 1.00 COMPZ2 WELLPR CIRC T CBU to ensure no gas in wellbore. 7,162.3 7,162.3 11:45 12:45 Pump @ 200 gpm=408 psi w/6%flow out.No gas at BU or pit gain observed. Page 48/55 Report Printed: 12/28/2016 • Oof perations Summary (with Timelogtepths) 2S-13 CormacaPhillips Auks Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/9/2016 12/9/2016 2.25 COMPZ2 WELLPR TRIP T RIH from 7,195'to 9,940'. 7,162.3 9,928.3 12:45 15:00 12/9/2016 12/9/2016 2.00 COMPZ2 WELLPR -CIRC T CBU to check for gas or influx.200 9,928.3 9,928.3 15:00 17:00 GPM 516 psi.No influx noted. 12/9/2016 12/9/2016 2.00 COMPZ2 -WELLPR CIRC T Circulated and increased MW to 10.4+ 9,928.3 9,928.3 17:00 19:00 PPG.200 GPM 471 psi.Lost 13 Bbls while circulating. 12/9/2016 12/9/2016 0.50 COMPZ2 WELLPR OWFF T OWFF slight loss Est 1 BPH. 9,928.3 9,928.3 19:00 19:30 12/9/2016 12/9/2016 1.00 COMPZ2 WELLPR TRIP T POOH from 9,940'to7,174'Good Hole 9,928.3 7,162.3 19:30 20:30 Fill. 12/9/2016 12/9/2016 3.00 COMPZ2 WELLPR TRIP P POOH from 7,174'to 92'Good Hole 7,162.3 80.3 20:30 23:30 Fill. 12/9/2016 12/10/2016 0.50 COMPZ2 WELLPR BHAH P Layed down Baker running tool. 80.3 38.3 23:30 00:00 12/10/2016 12/10/2016 0.50 COMPZ2 WELLPR BHAH P Laid down MWD. 38.3 -11.8 00:00 00:30 12/10/2016 12/10/2016 1.50 COMPZ2 WHDBOP RURD P Pulled Wear Bushing and set Test -11.8 -11.8 00:30 02:00 Plug.RU to test BOP. 12/10/2016 12/10/2016 4.50 COMPZ2 WHDBOP BOPE P Tested BOPE with 4"and 4-1/2"test -11.8 -11.8 02:00 06:30 joint.250/3500 psi,charted for 5 minutes each.Witness waived by AOGCC Rep.Jeff Jones. Install 4"Test Joint and test: Test#1 -Annular,CV#1,#12,#13, #14,4"kill line valve on mud manifold, and 4"FOSV. Test#2-Upper 3-1/2"x 6"VBR's,CV #9,#11,mezzanine kill valve,and 4" dart valve. Test#3-CV#8,#10,and HCR Kill. Test#4-CV#6,#7,and manual kill. Test#5-Super choke to 1500 psi Test#6-Manual choke to 1500 psi Test#7-CV#2 and#5. Test#8-Lower 3-1/2"x 6"VBR's. Install 4-1/2"Test joint and test: Test#9-Annular,CV#3,#4,and#6 Test#10-Upper 3-1/2"x 6"VBR's, Lower IBOP,and HCR choke. Test#11 -Manual choke and Upper IBOP Test#12-Lower 3-1/2"x 6"VBR's Test#13-Blind rams Perform Koomey draw down test. Observed initial system pressure at ACC-2925 PSI,MAN-1525 PSI. After Closure observed ACC-1725 PSI,200 PSI increase in 5 seconds, full pressure at 52 seconds. Drawdown test performed w/2 electric pumps and 2 x air pumps.Observed 6 nitrogen bottles with an average PSI of 2600 PSI. Tested all gas and PVT alarms,both audio and visual-good tests.Note that the upper IBOP failed initial test- after functioning and greasing once,it re-tested good. 12/10/2016 12/10/2016 1.00 COMPZ2 WHDBOP RURD P RD Test Equipment and reset Wear -11.8 -11.8 06:30 07:30 Bushing. Page 49/55 Report Printed: 12/28/2016 ; operations Summary (with Timelogtepths) 25-13 Conoiliips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start lime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/10/2016 12/10/2016 1.00 COMPZ2 RWRID RURD P Rig up casing Equipment to run LEM. -11.8 -11.8 07:30 08:30 12/10/2016 12/10/2016 2.50 COMPZ2 RWRID `PUTB P Made up LEM per Backer Rep and -11.8 302.3 08:30 11:00 oriented with MWD. 12/10/2016 12/10/2016 1.50 COMPZ2 RWRID RCST P RIH from 314'to 2,208'with LEM on 302.3 2,196.3 11:00 12:30 4"DP. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID DHEQ P Shallow Tested MWD. 2,196.3 2,196.3 12:30 12:45 12/10/2016 12/10/2016 4.00 COMPZ2 RWRID RCST P RIH from 2,208'to 10,209'with LEM 2,196.3 10,197.3 12:45 16:45 on 4"DP.UW 195K DW 127K. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID WASH P Made up Top Drive and wash down 10,197.3 10,221.3 16:45 17:00 from 10,209'to 10,233'127 GPM 590 psi. Unable to enter Top of Liner.Set down 15K.UW 205K DW 128K. 12/10/2016 12/10/2016 2.25 COMPZ2 RWRID WASH T Attempted to enter Top of Liner 10,221.3 10,221.3 17:00 19:15 Rotating Tool Face working down torque and taging with 30K.GPM 127 PSI 590.UW 201K DW 126K.No Success. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID TRIP T POOH from 10,233'to 10,206'. 10,221.3 10,194.3 19:15 19:30 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,194.3 10,194.3 19:30 19:45 12/10/2016 12/11/2016 4.25 COMPZ2 RWRID TRIP T. POOH from 10,206'to 315'. 10,194.3 303.3 19:45 00:00 12/11/2016 12/11/2016 0.75 COMPZ2 RWRID RURD T PJSM, R/U casing tongs and 303.3 298.3 00:00 00:45 elevators and prep to L/D LEM assembly. 12/11/2016 12/11/2016 1.50 COMPZ2 RWRID BHAH T L/D LEM assembly and MWD tools as 298.3 -11.8 00:45 02:15 per Baker rep and SLB MWD rep. 12/11/2016 12/11/2016 1.25 COMPZ2 RWRID BHAH T Clean and clear rig floor.L/D casing -11.8 -11.8 02:15 03:30 tongs and handling equipment via beaver slide. 12/11/2016 12/11/2016 1.50 COMPZ2 RWRID SLPC T PJSM,Cut and slip 59'of drilling line, -11.8 -11.8 03:30 05:00 4 wraps. 12/11/2016 12/11/2016 1.00 COMPZ2 RWRID -SVRG T Service rig,service top drive,blocks, -11.8 -11.8 05:00 06:00 iron roughneck and draw works. 12/11/2016 12/11/2016 1.50 COMPZ2 RWRID RURD T PJSM,R/U power tongs and dress f/3 -11.8 -11.8 06:00 07:30 -1/8".Mobilize Baker fishing tools to rig floor,load pipe shed w/2-7/8"PAC pipe and strap. 12/11/2016 12/11/2016 1.25 COMPZ2 RWRID BHAH T M/U clean out BHA as per Baker.3- -11.8 94.3 07:30 08:45 3/4"Smooth OD convex mill,1 joint 2- 7/8"PAC,4-3/4"Smooth OD string mill, 1 joint 2-7/8"PAC pipe and string magnets. 12/11/2016 12/11/2016 4.75 COMPZ2 RWRID TRIP T RIH from 106'to 10,007'UW 180K 94.3 9,995.3 08:45 13:30 DW 130K. 12/11/2016 12/11/2016 4.25 COMPZ2 RWRID REAM T Washed down with mill bha from 9,995.3 10,299.3 13:30 17:45 10,106'to 10,311'.Tagged @ 10,233' and was free below 10,234'.Reamed out from 10,244'to 10,311'with 7-9K WOB 40-60 RPM.171 GPM @ 814 PSI.UW 190K DW 132K RW 152K Tq 6K. 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID PULD T Laid down 2 singles to 10,310'. 10,299.3 10,298.3 17:45 18:00 Page 50/55 Report Printed: 12/28/2016 llgperations Summary (with Timelo ge the g p ) 7 , 0_ 2S-13 ConocoPhiilips , Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (WS) End Depth(ftKB) 12/11/2016 12/11/2016 3.75 COMPZ2 RWRID CIRC T Circulated Rot and Recip with 213 to 10,298.3 10,298.3 18:00 21:45 256 GPM 1200 psi to 1490 psi.50 RPM Tq 7-9K.Pumped 3 sweeps to clean hole. 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID PULD T Laid down 1 single. 10,298.3 10,268.3 21:45 22:00 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,268.3 10,268.3 22:00 22:15 12/11/2016 12/12/2016 1.75 COMPZ2 RWRID TRIP T POOH from 10,280'to 7,304'.UW 10,268.3 7,292.3 22:15 00:00 134K DW 100K. 12/12/2016 12/12/2016 2.75 COMPZ2 RWRID TRIP T POOH frpm 7,304'to 104'. 7,292.3 92.3 00:00 02:45 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static 92.3 92.3 02:45 03:00 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID BHAH T Laid down BHA. 92.3 -11.8 03:00 04:00 12/12/2016 12/12/2016 0.75 COMPZ2 RWRID BHAH T Cleaned off Rig Floor. -11.8 -11.8 04:00 04:45 12/12/2016 12/12/2016 1.25 COMPZ2 RWRID BHAH T Made up and ran in LEM Assembly to -11.8 302.3 04:45 06:00 314'. 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID RCST -T RIH with LEM on 4"DP from 314'to 302.3 2,193.3 06:00 07:00 2,205'. 12/12/2016 12/12/2016 0.50 COMPZ2 RWRID DHEQ T Shallow tested MWD.Working. 2,193.3 2,193.3 07:00 07:30 12/12/2016 12/12/2016 4.00 COMPZ2 RWRID RCST T RIH with LEM on 4"DP from 2,205'to 2,193.3 10,013.3 07:30 11:30 10,025'. 12/12/2016 12/12/2016 3.00 COMPZ2 RWRID WASH T Washed down orienting LEM from 10,013.3 10,232.3 11:30 14:30 10,025'to 10,244'.Washed and worked pipe from 10,217 to 10,244' tagging with 15K,would not seat. 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID TRIP T POOH 1 stand and blow down top 10,232.3 10,232.3 14:30 14:45 drive. 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,232.3 10,232.3 14:45 15:00 12/12/2016 12/12/2016 4.50 COMPZ2 RWRID TRIP T POOH from 10,244'to 314'. 10,232.3 302.3 15:00 19:30 12/12/2016 12/12/2016 2.00 COMPZ2 RWRID BHAH T 'Laid down LEM assembly. 302.3 -11.8 19:30 21:30 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID BHAH T Cleared components off Rig Floor. -11.8 -11.8 21:30 22:30 12/12/2016 12/13/2016 1.50 COMPZ2 RWRID BHAH T Made up Cleanout BHA with -11.8 53.3 22:30 00:00 Reverseing Basket. 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID BHAH T Finish making up Cleanout BHA. 53.3 290.3 00:00 01:15 12/13/2016 12/13/2016 3.75 COMPZ2 RWRID TRIP T RIH with Cleanout BHA from 302'to 290.3 10,001.3 01:15 05:00 10,013'. 12/13/2016 12/13/2016 2.25 COMPZ2 RWRID WASH T Wash down with reverse Basket from 10,001.3 10,282.3 05:00 07:15 10,013'to 10,294'.Took weight at 10,244'and washed through. Remainder took 2 to 5K while washing down. 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID CIRC T Pumped down ball to open Pump Out 10,282.3 10,282.3 07:15 07:45 Sub.3 BPM 560 psi. 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID CIRC T Pumped Viscus Pill and circulated out. 10,282.3 10,282.3 07:45 09:00 8 BPM 2214 psi. 12/13/2016 12/13/2016 0.25 COMPZ2 RWRID OWFF T OWFF well Static. 10,282.3 10,282.3 09:00 09:15 12/13/2016 12/13/2016 4.50 COMPZ2 RWRID TRIP T POOH from 10,294'to 302'. 10,282.3 290.3 09:15 13:45 Page 51/55 Report Printed: 12/28/2016 Jag ink operations Summary (with Timeloggepths) 0:21' 2S-13 ConocoPhillips , Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID BHAH T Cleaned Magnets and laid down BHA. 290.3 -11.8 13:45 15:00 Emty Reverse Baskit and redress. 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID BHAH T Cleaned Rig Floor. -11.8 -11.8 15:00 15:30 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID SVRG T Serviced Rig. -11.8 -11.8 15:30 16:00 12/13/2016 12/13/2016 1.00 COMPZ2 RWRID BHAH T " Made up BHA with Reversre Basket -11.8 290.3 16:00 17:00 and Magnets. 12/13/2016 12/13/2016 4.50 COMPZ2 RWRID TRIP T RIH from 302'to 10,203'. 290.3 10,191.3 17:00 21:30 12/13/2016 12/13/2016 1.50 COMPZ2 RWRID WASH T Washed down from 10,203'to 10,296'. 10,191.3 10,284.3 21:30 23:00 Tagged with 4K at 10,296'.Worked Basket.6 BPM 2,055 psi.30 RPM Tq 6-9K.RW 147K. 12/13/2016 12/13/2016 0.25 COMPZ2 RWRID CIRC T Pumped down ball to open Pump Out 10,284.3 10,284.3 23:00 23:15 Sub.3 BPM 575 psi. 12/13/2016 12/14/2016 0.75 COMPZ2 RWRID CIRC T Pumped Viscus Pill and circulated at. 10,284.3 10,284.3 23:15 00:00 8 BPM 2110 psi. 12/14/2016 12/14/2016 0.50 COMPZ2 RWRID CIRC T Circulated Viscous Pill out at.8 BPM 10,284.3 10,284.3 00:00 00:30 2110 psi. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID 'OWFF T OWFF Well Static. 10,284.3 10,284.3 00:30 00:45 12/14/2016 12/14/2016 4.00 COMPZ2 RWRID TRIP T POOH from 10,296'to 302'. 10,284.3 290.3 00:45 04:45 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 290.3 290.3 04:45 05:00 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID BHAH T Cleaned Magnets and laid down BHA. 290.3 -11.8 05:00 06:30 12/14/2016 12/14/2016 2.00 COMPZ2 RWRID BHAH T Redressed Reverse Basket and made -11.8 290.3 06:30 08:30 up Cleanout BHA. 12/14/2016 12/14/2016 4.00 COMPZ2 RWRID TRIP T RIH with Cleanout BHA from 302'to 290.3 9,998.3 08:30 12:30 10,010'. 12/14/2016 12/14/2016 3.75 COMPZ2 RWRID WASH T Washed down from 10,010'to 9,998.3 10,284.1 12:30 16:15 10,295.87'.Tagged with 5-8K WOB at 10,295.87'.Worked Basket.254 GPM 1,955 psi.30-60 RPM Tq 5-6K. RW 154K. 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID CIRC T Dropped ball and opened PO sub. 10,284.1 10,284.2 16:15 17:45 Continued circulating 8 BPM 2197 psi. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID PULD T Laid down single and blow down Top 10,284.2 10,273.3 17:45 18:00 Drive. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,273.3 10,273.3 18:00 18:15 12/14/2016 12/14/2016 3.75 COMPZ2 RWRID TRIP T POOH from 10,285'to 314'. 10,273.3 302.3 18:15 22:00 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID BHAH T Laid down BHA Cleaned Magnets and 302.3 -11.8 22:00 23:30 Junk Basket!/3rd full. 12/14/2016 12/15/2016 0.50 COMPZ2 RWRID 'BHAH T Clear componets off Rig Floor. -11.8 -11.8 23:30 00:00 12/15/2016 12/15/2016 0.50 COMPZ2 RWRID BHAH T Finish laying down BHA. -11.8 -11.8 00:00 00:30 12/15/2016 12/15/2016 0.75 COMPZ2 RWRID BHAH T Cleared Rig floor and chamged -11.8 -11.8 00:30 01:15 Equipment. 12/15/2016 12/15/2016 3.50 COMPZ2 RWRID PUTB T Picked up LEM BHA with inner string -11.8 302.3 01:15 04:45 and MWD and made up per Baker Rep and Detail. Page 52/55 Report Printed: 12/28/2016 =' itperations Summary (with Timelog epths) 2S-13 ConocoPhiliiips rd.�A.3 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/15/2016 12/15/2016 1.00 COMPZ2 RWRID RCST T RIH with LEM on 4"DP from 314'to 302.3 2,188.3 04:45 05:45 2,200'. 12/15/2016 12/15/2016 0.50 COMPZ2 RWRID DHEQ T Shallow tested MWD 120 GPM 260 2,188.3 2,188.3 05:45 06:15 psi. 12/15/2016 12/15/2016 3.50 COMPZ2 RWRID RCST T RIH with LEM on 4"DP from 2,200'to 2,188.3 9,921.3 06:15 09:45 9,933'. 12/15/2016 12/15/2016 3.00 COMPZ2 RWRID WASH T Washed down from 9,933'to 10,285'. 9,921.3 10,273.3 09:45 12:45 120 GPM 516 psi.UW 174K DW 129K.Orient Tool Face andTagged Latch with 20K no movement. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID TRIP T POOH from 10,285'to 10,045'.UW 10,273.3 10,033.3 12:45 13:00 178K. 12/15/2016 12/15/2016 1.50 COMPZ2 RWRID CIRC T Circulated and oriented Tool Face to 10,033.3 10,008.3 13:00 14:30 Jet Latch. 139 GPM 640 psi.UW 178K DW 135K. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID TRIP T RIH from 10,020'to 10,209'. 10,008.3 10,197.3 14:30 14:45 12/15/2016 12/15/2016 4.75 COMPZ2 RWRID WASH T Washed Latch and worked pipe to 10,197.3 10,275.3 14:45 19:30 reorint Tool Face.Attempted to Latch 3 times.No success latching in. Continued to wash and orient LEM while regrouped with Anchorage Team.Oriented Tool Face to 17 Left and set down 50K per Baker. 12/15/2016 12/15/2016 1.25 COMPZ2 RWRID PACK P Dropped 1.5"Ball and pumped down 10,275.3 10,275.3 19:30 20:45 to seat.Pressured up to 2,500 psi and set ZXP Packer.Pressured up to 3800 psi and released running tool. 12/15/2016 12/15/2016 0.75 COMPZ2 RWRID PRTS P PU to nuetral weight and Tested IA to 10,275.3 10,273.3 20:45 21:30 3500 psi for 10 Min on Chart. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID PACK P Picked up and retagged 4'high 10,273.3 10,273.3 21:30 21:45 comfirming LEM set. 12/15/2016 12/15/2016 0.50 COMPZ2 RWRID OWFF P OWFF Well Static. 10,273.3 10,273.3 21:45 22:15 12/15/2016 12/16/2016 1.75 COMPZ2 RWRID PULD P POOH Laying Down DP from 10,285' 10,273.3 8,757.3 22:15 00:00 to 8,769'. 12/16/2016 12/16/2016 7.50 COMPZ2 RWRID PULD P POOH laying down DP from 8,769'to 8,757.3 302.3 00:00 07:30 314'. 12/16/2016 12/16/2016 0.25 COMPZ2 RWRID OWFF P OWFF Well Static. 302.3 302.3 07:30 07:45 12/16/2016 12/16/2016 0.50 COMPZ2 RWRID PULD P Laid down 4 Stands of DP from 302.3 302.3 07:45 08:15 Derreck in mousehole. 12/16/2016 12/16/2016 0.25 COMPZ2 RWRID BHAH P RU power tongs for inner string. 302.3 302.3 08:15 08:30 12/16/2016 12/16/2016 1.50 COMPZ2 RWRID -BHAH P Laid down Baker running tool and 302.3 -11.8 08:30 10:00 inner String with MWD. 12/16/2016 12/16/2016 0.75 COMPZ2 RWRID BHAH P Cleared Rig Floor. -11.8 -11.8 10:00 10:45 12/16/2016 12/16/2016 7.25 COMPZ2 RPCOMP PULD P Laid down 66 Stands of DP from -11.8 -11.8 10:45 18:00 Derreck in mousehole. 12/16/2016 12/16/2016 1.50 COMPZ2 RPCOMP WWWH P Pulled Wear Bushing.RU Stack Wash -11.8 -11.8 18:00 19:30 Tool and Washed Stack. 12/16/2016 12/16/2016 0.75 COMPZ2 RPCOMP RURD P Rigged up to run Upper Completion. -11.8 -11.8 19:30 20:15 12/16/2016 12/17/2016 3.75 COMPZ2 'RPCOMP PUTB P Make up and Run 4.5"Upper -11.8 1,765.3 20:15 00:00 Completion per Detail to 1,777'. Page 53/55 Report Printed: 12/28/2016 Operations Summary (with • 0,� Timelo De the) 9 p r. 2S-13 CortocoPhiiiips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/17/2016 12/17/2016 9.25 COMPZ2 RPCOMP PUTB P Make up and Run 4.5"Upper 1,765.3 10,011.3 00:00 09:15 Completion per Detail from 1,777' to 10,023'.Tagged No Go with 10K. 12/17/2016 12/17/2016 1.75 COMPZ2 RPCOMP HOSO P Laid down 4 Jts of Tubing.PU 3 Jts of 10,011.3 10,008.3 09:15 11:00 Tubing and tagged @ 10,013'. Washed top og Seal Bore 5BPM 447 psi.Entered Seal Bore pumping 2 BPM 60 psi.Confirmed entry with increase to 140 psi. Ran in to 10,020'. 12/17/2016 12/17/2016 0.50 COMPZ2 RPCOMP PRTS P Tested IA to 500 psi for 5 Min on 10,008.3 10,008.3 11:00 11:30 Chart to confirm seals engaged. 12/17/2016 12/17/2016 1.50 COMPZ2 RPCOMP HOSO P Spaced out.Added 2 Pups 7.82'+ 10,008.3 9,962.3 11:30 13:00 3.90'. 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP THGR P Made up Tubing Hanger and Landing 9,962.3 9,962.3 13:00 14:00 Joint. 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP CRIH P Pumped 69 Bbls Inhibited Brine 9,962.3 9,962.3 14:00 15:00 displaced with 137 Bbls Brine.5 BPM 500 psi. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP THGR P Drained Stack and Landed Tubing. 9,962.3 10,007.3 15:00 15:15 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP THGR P Ran in Lock Down Screws and tested 10,007.3 -11.8 15:15 16:15 Tubing Hanger 5,000 psi for 10 Min. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP PRTS P 'Dropped Ball and Rod. -11.8 -11.8 16:15 16:30 12/17/2016 12/17/2016 1.75 COMPZ2 RPCOMP PRTS P Pressure tested Tubing 3,500 psi for -11.8 -11.8 16:30 18:15 30 Min on chart.Tested IA 3,500 psi for 30 Min on chart.Both test good. 12/17/2016 12/17/2016 0.75 COMPZ2 RPCOMP CIRC P Pressured up IA to 2,590 psi and -11.8 -11.8 18:15 19:00 Sheared out Valve.Checked circulation both ways. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP OWFF P OWFF Well Static -11.8 -11.8 19:00 19:15 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP RURD P RD and laid down Landing Joint. -11.8 -11.8 19:15 19:30 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP MPSP P Installed Type H BPV and Tested -11.8 -11.8 19:30 20:15 2,500 psi for 10 Min on chart. 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP OWFF P OWFF for 30 Min.Well Static. -11.8 -11.8 20:15 21:00 12/17/2016 12/17/2016 1.25 COMPZ2 WHDBOP OTHR P Cleared Rig Floor and Blow down -11.8 -11.8 21:00 22:15 lines. 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP MPDA P Pulled Trip Nipple. -11.8 -11.8 22:15 23:00 12/17/2016 12/18/2016 1.00 COMPZ2 WHDBOP MPDA P Cleaned and removed RCD Clamp -11.8 -11.8 23:00 00:00 and AV valve from Stack. 12/18/2016 12/18/2016 1.00 COMPZ2 WHDBOP MPDA P Removed RCD Clamp and AV valve 0.0 0.0 00:00 01:00 from Stack. 12/18/2016 12/18/2016 3.50 COMPZ2 WHDBOP OTHR T ND Annular and remove from Stack. 0.0 0.0 01:00 04:30 NU new Annular. 12/18/2016 12/18/2016 1.25 COMPZ2 WHDBOP NUND P ND BOP and set back. 0.0 0.0 04:30 05:45 12/18/2016 12/18/2016 2.75 COMPZ2 WHDBOP NUND P Dressed Hanger and NU Adapter 0.0 0.0 05:45 08:30 Flange.Installed Test Dart. 12/18/2016 12/18/2016 0.25 COMPZ2 WHDBOP PRTS P Tested void 250/5000 psi for 5 Min. 0.0 0.0 08:30 08:45 12/18/2016 12/18/2016 2.25 COMPZ2 WHDBOP NUND P NU Tree. 0.0 0.0 08:45 11:00 Page 54/55 Report Printed: 12/28/2016 Operations Summary (with TimelogPe ths) 2S--13 ConocoPhiilips Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/18/2016 12/18/2016 0.25 COMPZ2 WHDBOP PRTS P Tested Tree to 250/5000 psi for 15 0.0 0.0 11:00 11:15 Min. 12/18/2016 12/18/2016 0.75 COMPZ2 WHDBOP MPSP P Pulled Test Dart and BPV. 0.0 0.0 11:15 12:00 12/18/2016 12/18/2016 1.00 COMPZ2 WHDBOP FRZP P Rigged up to Freeze protect well. 0.0 0.0- 12:00 13:00 12/18/2016 12/18/2016 0.251COMPZ2 WHDBOP FRZP P ' Tested lines 2000 psi.With LRS. 0.0 0.0' 13:00 13:15 12/18/2016 12/18/2016 1.25'COMPZ2 WHDBOP -FRZP P Pumped 91 Bbls Diesel with LRS 0.0 0.0 13:15 14:30 down IA. 12/18/2016 12/18/2016 1.25 COMPZ2 WHDBOP FRZP P Allowed IA and Tubing to U Tube. 0.0 0.0 14:30 15:45 12/18/2016 12/18/2016 1.75-COMPZ2 WHDBOP MPSP P Installed Lubricator tested to 2000 psi 0.0 0.0 . 15:45 17:30 and Set BPV.Laid down Lubricator. I 12/18/2016 I 12/18/2016 1.00 COMPZ2 MOVE RURD P Rigged down test lines and trimmed 0.0 0.0 17:30 18:30 Tree.Secured Well.Tubing 325 PSI (Before BPV),IA 50 PSI,OA 25 PSI. Rig released to Move @ 1900 Hrs 12/18/16. 12/18/2016 12/18/2016 0.50 DEMOB MOVE -RURD P Prep to move to 1D-37.Rig released 0.0 -11.8 18:30 19:00 @ 1900 hrs 12-18-2016 for'23 mile I move. Page 55/55 Report Printed: 12/28/2016 • i NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-13A Definitive Survey Report 14 December, 2016 • Schlumberger 1 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-13 Well Position +N/-S 0.00 usft Northing: 5,929,948.70 usft Latitude: 70°13'11.187 N +E/-W 0.00 usft Easting: 480,898.09 usft Longitude: 150°9'14.767 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore 2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2016 12/1/2016 17.71 80.84 57,531 Design 2S-13A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,752.87 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft)', (usft) (usft) (0) 39.10 0.00 0.00 20.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 94.28 1,295.18 2S-13PB1 Srvy#1-SLB_NSG+Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2; 1,316.39 2,787.14 2S-13PB1 Srvy#2-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:2i 2,879.81 8,752.87 2S-13PB1 Srvy#3-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 8,847.00 9,224.66 2S-13A Srvy 1-SLB_INC+Filler(2S-13A INC+TREND Inclinometer+known azi trend 11/10/2016 11:15 9,318.30 10,350.09 2S-13A Srvy 2-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2016 11:2' 10,350.09 16,856.69 2S-13A Srvy 3-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/18/2016 9:48 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (f) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,948.70 480,898.09 0.00 0.00 UNDEFINED 94.28 0.03 287.05 94.28 -64.82 0.00 -0.01 5,929,948.70 480,898.08 0.05 0.00 GYD-GC-SS(1) 119.10 0.04 238.86 119.10 -40.00 0.00 -0.03 5,929,948.70 480,898.06 0.11 -0.01 GYD-GC-SS(1) 20"x 42" 186.46 0.10 201.50 186.46 27.36 -0.06 -0.07 5,929,948.64 480,898.02 0.11 -0.08 GYD-GC-SS(1) 278.50 0.54 204.98 278.50 119.40 -0.53 -0.28 5,929,948.17 480,897.81 0.48 -0.59 GYD-GC-SS(1) 370.52 2.63 196.47 370.48 211.38 -2.95 -1.06 5,929,945.75 480,897.02 2.28 -3.13 GYD-GC-SS(1) 462.15 4.08 197.58 461.95 302.85 -8.07 -2.64 5,929,940.63 480,895.43 1.58 -8.49 GYD-GC-SS(1) 554.04 4.84 198.23 553.56 394.46 -14.87 -4.84 5,929,933.84 480,893.21 0.83 -15.63 GYD-GC-SS(1) 645.95 5.99 202.27 645.06 485.96 -22.99 -7.87 5,929,925.73 480,890.16 1.32 -24.30 GYD-GC-SS(1) 12/14/2016 8'57'15AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • 1 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) O (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100'), (ft) Survey Tool Name 737.60 6.53 203.78 736.16 577.06 -32.19 -11.79 5,929,916.55 480,886.22 0.62 -34.28 GYD-GC-SS(1) 829.54 8.48 201.86 827.31 668.21 -43.26 -16.42 5,929,905.48 480,881.56 2.14 -46.27 GYD-GC-SS(1) 922.16 9.80 205.54 918.75 759.65 -56.71 -22.36 5,929,892.05 480,875.59 1.56 -60.94 GYD-GC-SS(1) 1,015.46 11.08 208.23 1,010.51 851.41 -71.78 -30.02 5,929,877.01 480,867.89 1.47 -77.72 GYD-GC-SS(1) 1,107.69 12.93 209.29 1,100.72 941.62 -88.59 -39.27 5,929,860.22 480,858.60 2.02 -96.67 GYD-GC-SS(1) 1,200.16 15.38 208.11 1,190.37 1,031.27 -108.43 -50.11 5,929,840.41 480,847.72 2.67 -119.03 GYD-GC-SS(1) 1,295.18 19.22 206.89 1,281.08 1,121.98 -133.50 -63.12 5,929,815.37 480,834.64 4.06 -147.04 GYD-GC-SS(1) 1,316.39 20.60 207.96 1,301.02 1,141.92 -139.91 -66.45 5,929,808.97 480,831.29 6.73 -154.20 MWD+IFR-AK-CAZ-SC(2) 1,408.27 21.80 208.96 1,386.68 1,227.58 -169.12 -82.29 5,929,779.81 480,815.38 1.36 -187.06 MWD+IFR-AK-CAZ-SC(2) 1,502.81 25.56 213.09 1,473.25 1,314.15 -201.58 -101.93 5,929,747.40 480,795.66 4.34 -224.28 MVVD+IFR-AK-CAZ-SC(2) 1,596.76 27.45 217.68 1,557.33 1,398.23 -235.70 -126.24 5,929,713.34 480,771.27 2.97 -264.66 MWD+IFR-AK-CAZ-SC(2) 1,689.53 29.30 221.23 1,638.96 1,479.86 -269.70 -154.27 5,929,679.41 480,743.15 2.70 -306.20 MWD+IFR-AK-CAZ-SC(2) 1,783.35 30.21 225.91 1,720.42 1,561.32 -303.40 -186.36 5,929,645.81 480,710.98 2.66 -348.84 MWD+IFR-AK-CAZ-SC(2) 1,875.34 31.06 226.45 1,799.57 1,640.47 -335.85 -220.19 5,929,613.44 480,677.08 0.97 -390.90 MVVD+IFR-AK-CAZ-SC(2) 1,968.32 32.83 229.72 1,878.47 1,719.37 -368.68 -256.80 5,929,580.71 480,640.38 2.66 -434.28 MWD+IFR-AK-CAZ-SC(2) 2,061.97 33.68 233.62 1,956.79 1,797.69 -400.50 -297.08 5,929,549.00 480,600.02 2.46 -477.95 MWD+IFR-AK-CAZ-SC(2) 2,154.77 34.26 235.37 2,033.75 1,874.65 -430.60 -339.29 5,929,519.00 480,557.74 1.23 -520.68 MWD+IFR-AK-CAZ-SC(2) 2,249.17 35.48 238.69 2,111.21 1,952.11 -459.94 -384.57 5,929,489.78 480,512.40 2.39 -563.74 MWD+IFR-AK-CAZ-SC(2) 2,342.07 38.90 240.04 2,185.21 2,026.11 -488.53 -432.89 5,929,461.32 480,464.01 3.78 -607.12 MWD+IFR-AK-CAZ-SC(2) 2,435.49 39.45 242.06 2,257.63 2,098.53 -517.09 -484.53 5,929,432.89 480,412.31 1.49 -651.62 MWD+IFR-AK-CAZ-SC(2) 2,526.64 40.79 245.52 2,327.34 2,168.24 -543.00 -537.21 5,929,407.12 480,359.56 2.85 -693.99 MWD+IFR-AK-CAZ-SC(2) 2,620.76 42.70 247.70 2,397.57 2,238.47 -567.85 -594.73 5,929,382.41 480,301.98 2.55 -737.01 MWD+IFR-AK-CAZ-SC(2) 2,713.46 43.56 247.40 2,465.22 2,306.12 -592.05 -653.30 5,929,358.36 480,243.36 0.95 -779.79 MWD+IFR-AK-CAZ-SC(2) 2,787.14 45.32 247.46 2,517.82 2,358.72 -611.85 -700.94 5,929,338.69 480,195.68 2.39 -814.69 MWD+IFR-AK-CAZ-SC(2) 2,846.60 46.00 247.45 2,559.38 2,400.28 -628.16 -740.21 5,929,322.48 480,156.37 1.14 -843.44 MWD+IFR-AK-CAZ-SC(3) 13-3/8"x16" 2,879.61 46.37 247.44 2,582.24 2,423.14 -637.29 -762.21 5,929,313 40 480,134.35 1.14 -859.55 MWD+IFR-AK-CAZ-SC(3) 2,973.48 45.93 246.36 2,647.27 2,488.17 -663.85 -824.47 5,929,287.01 480,072.02 0.95 -905.80 MWD+IFR-AK-CAZ-SC(3) 3,064.84 45.12 245.87 2,711 27 2,552.17 -690.24 -884.08 5,929,260.77 480,012.35 0.97 -950.99 MWD+IFR-AK-CAZ-SC(3) 3,156.72 45.68 246.79 2,775.79 2,616.69 -716.50 -944.00 5,929,234.66 479,952.38 0.94 -996.16 MWD+IFR-AK-CAZ-SC(3) 3,249.58 47.31 247.54 2,839.71 2,680.61 -742.63 -1,006.07 5,929,208.69 479,890.24 1.85 -1,041.94 MWD+IFR-AK-CAZ-SC(3) 3,344.32 50.46 248.03 2,902.00 2,742.90 -769.61 -1,072.14 5,929,181.88 479,824.11 3.35 -1,089.89 MWD+IFR-AK-CAZ-SC(3) 3,437.25 51.28 247.93 2,960.65 2,801.55 -796.64 -1,138.97 5,929,155.03 479,757.22 0.89 -1,138.15 MWD+IFR-AK-CAZ-SC(3) 3,530.59 55.39 247.67 3,016.37 2,857.27 -824.93 -1,208.28 5,929,126.92 479,687.85 4.41 -1,188.43 MWD+IFR-AK-CAZ-SC(3) 3,621.02 56.46 248.04 3,067.04 2,907.94 -853.16 -1,277.65 5,929,098.86 479,618.41 1.23 -1,238.69 MWD+IFR-AK-CAZ-SC(3) 3,714.87 57.86 248.01 3,117.93 2,958.83 -882.67 -1,350.77 5,929,069.54 479,545.22 1.49 -1,291.43 MWD+IFR-AK-CAZ-SC(3) 3,806.95 58.60 248.24 3,166.41 3,007.31 -911.83 -1,423.42 5,929,040.56 479,472.51 0.83 -1,343.68 MWD+IFR-AK-CAZ-SC(3) 3,900.29 62.00 248.65 3,212.65 3,053.55 -941.61 -1,498.82 5,929,010.98 479,397.04 3.66 -1,397.45 MWD+IFR-AK-CAZ-SC(3) 3,994.62 62.42 248.93 3,256.63 3,097.53 -971.80 -1,576.62 5,928,980.99 479,319.18 0.52 -1,452.43 MWD+IFR-AK-CAZ-SC(3) 4,086.87 61.97 248.44 3,299.66 3,140.56 -1,001.46 -1,652.63 5,928,951.52 479,243.09 0.68 -1,506.30 MWD+IFR-AK-CAZ-SC(3) 12/14/2016 8•57•15AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.1 ousft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD *NOSS +#I$ +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,179.93 61.01 250.91 3,344.09 3,184.99 -1,029.87 -1,729.30 5,928,923.31 479,166.36 2.55 -1,559.22 MWD+IFR-AK-CAZ SC(3) 4,273.79 60.59 251.46 3,389.88 3,230.78 -1,056.29 -1,806.86 5,928,897.09 479,088.74 0.68 -1,610.57 MWD+IFR-AK-CAZ-SC(3) 4,368.17 60.80 251.48 3,436.07 3,276.97 -1,082.45 -1,884.89 5,928,871.13 479,010.65 0.22 -1,661.84 MWD+IFR-AK-CAZ-SC(3) 4,461.58 61.03 251.32 3,481.48 3,322.38 -1,108.49 -1,962.26 5,928,845.29 478,933.23 0.29 -1,712.77 MWD+IFR-AK-CAZ-SC(3) 4,556.36 61.00 251.15 3,527.41 3,368.31 -1,135.16 -2,040.76 5,928,818.82 478,854.67 0.16 -1,764.68 MWD+IFR-AK-CAZ-SC(3) 4,650.19 61.06 250.63 3,572.86 3,413.76 -1,162.03 -2,118.33 5,928,792.15 478,777.04 0.49 -1,816.46 MWD+IFR-AK-CAZ-SC(3) 4,743.61 60.86 249.57 3,618.21 3,459.11 -1,189.83 -2,195.12 5,928,764.55 478,700.18 1.01 -1,868.85 MVVD+IFR-AK-CAZ-SC(3) 4,837.87 60.79 250.20 3,664.16 3,505.06 -1,218.13 -2,272.40 5,928,736.44 478,622.84 0.59 -1,921.88 MWD+IFR-AK-CAZ-SC(3) 4,928.53 61.06 250.33 3,708.21 3,549.11 -1,244.89 -2,346.99 5,928,709.88 478,548.19 0.32 -1,972.53 MWD+IFR-AK-CAZ-SC(3) 5,021.88 61.10 250.12 3,753.36 3,594.26 -1,272.53 -2,423.88 5,928,682.43 478,471.24 0.20 -2,024.81 MWD+IFR-AK-CAZ-SC(3) 5,114.38 60.72 250.05 3,798.33 3,639.23 -1,300.07 -2,499.87 5,928,655.09 478,395.18 0.42 -2,076.67 MWD+IFR-AK-CAZ-SC(3) 5,206.88 60.66 249.61 3,843.61 3,684.51 -1,327.88 -2,575.59 5,928,627.48 478,319.41 0.42 -2,128.70 MWD+IFR-AK-CAZ-SC(3) 5,300.97 60.74 250.17 3,889.66 3,730.56 -1,356.09 -2,652.64 5,928,599.46 478,242.29 0.53 -2,181.56 MWD+IFR-AK-CAZ-SC(3) 5,393.35 60.67 250.09 3,934.86 3,775.76 -1,383.47 -2,728.41 5,928,572.27 478,166.46 0.11 -2,233.21 MWD+IFR-AK-CAZ-SC(3) 5,485.05 60.63 250.62 3,979.80 3,820.70 -1,410.35 -2,803.68 5,928,545.60 478,091.13 0.51 -2,284.21 MWD+IFR-AK-CAZ-SC(3) 5,579.52 60.66 250.87 4,026.11 3,867.01 -1,437.50 -2,881.42 5,928,518.64 478,013.33 0.23 -2,336.31 MWD+IFR-AK-CAZ-SC(3) 5,673.28 60.74 251.47 4,072.00 3,912.90 -1,463.89 -2,958.80 5,928,492.45 477,935.88 0.56 -2,387.58 MWD+IFR-AK-CAZ-SC(3) 5,768.68 60.53 251.29 4,118.78 3,959.68 -1,490.44 -3,037.60 5,928,466.11 477,857.04 0.27 -2,439.47 MWD+IFR-AK-CAZ-SC(3) 5,862.17 60.90 250.91 4,164.51 4,005.41 -1,516.85 -3,114.74 5,928,439.89 477,779.83 0.53 -2,490.68 MWD+IFR-AK-CAZ-SC(3) 5,955.59 60.44 248.47 4,210.28 4,051.18 -1,545.11 -3,191.11 5,928,411.82 477,703.39 2.33 -2,543.35 MWD+IFR-AK-CAZ-SC(3) 6,048.82 60.79 249.67 4,256.03 4,096.93 -1,574.13 -3,266.99 5,928,383.00 477,627.45 1.18 -2,596.57 MWD+IFR-AK-CAZ-SC(3) 6,141.13 60.59 248.07 4,301.22 4,142.12 -1,603.14 -3,342.06 5,928,354.18 477,552.31 1.53 -2,649.51 MWD+IFR-AK-CAZ-SC(3) 6,234.01 60.88 248.38 4,346.62 4,187.52 -1,633.20 -3,417.31 5,928,324.32 477,477.00 0.43 -2,703.49 MWD+IFR-AK-CAZ-SC(3) 6,327.61 60.70 248.15 4,392.30 4,233.20 -1,663.45 -3,493.20 5,928,294.26 477,401.04 0.29 -2,757.88 MWD+IFR-AK-CAZ-SC(3) 6,420.92 60.61 250.20 4,438.03 4,278.93 -1,692.37 -3,569.22 5,928,265.54 477,324.96 1.92 -2,811.05 MWD+IFR-AK-CAZ-SC(3) 6,513.98 58.16 250.88 4,485.42 4,326.32 -1,719.05 -3,644.72 5,928,239.05 477,249.39 2.71 -2,861.95 MWD+IFR-AK-CAZ-SC(3) 6,609.81 58.41 253.51 4,535.80 4,376.70 -1,743.97 -3,722.33 5,928,214.33 477,171.73 2.35 -2,911.91 MWD+IFR-AK-CAZ-SC(3) 6,700.72 58.87 256.33 4,583.12 4,424.02 -1,764.16 -3,797.27 5,928,194.33 477,096.74 2.70 -2,956.51 MWD+IFR-AK-CAZ-SC(3) 6,795.26 59.28 258.89 4,631.71 4,472.61 -1,781.56 -3,876.47 5,928,177.14 477,017.51 2.36 -2,999.95 MWD+IFR-AK-CAZ-SC(3) 6,890.38 58.49 262.31 4,680.88 4,521.78 -1,794.87 -3,956.79 5,928,164.03 476,937.16 3.19 -3,039.92 MWD+IFR-AK-CAZ-SC(3) 6,986.56 57.42 266.31 4,731.92 4,572.82 -1,802.96 -4,037.89 5,928,156.14 476,856.05 3.70 -3,075.27 MWD+IFR-AK-CAZ-SC(3) 7,079.86 56.96 269.00, 4,782.48 4,623.38 -1,806.17 -4,116.23 5,928,153.13 476,777.71 2.47 -3,105.08 MWD+IFR-AK-CAZ-SC(3) 7,173.85 56.44 272.56 4,834.10 4,675.00 -1,805.11 -4,194.76 5,928,154.39 476,699.20 3.21 -3,130.94 MWD+IFR-AK-CAZ-SC(3) 7,265.88 55.85 275.87 4,885.38 4,726.28 -1,799.50 -4,270.96 5,928,160.19 476,623.01 3.05 -3,151.74 MWD+IFR-AK-CAZ-SC(3) 7,357.32 55.88 278.70 4,936.70 4,777.60 -1,789.91 -4,346.02 5,928,169.97 476,547.98 2.56 -3,168.39 MWD+IFR-AK-CAZ-SC(3) 7,452.65 55.03 280.27 4,990.75 4,831.65 -1,776.97 -4,423.47 5,928,183.10 476,470.58 1.62 -3,182.73 MWD+IFR-AK-CAZ-SC(3) 7,544.85 52.88 282.42 5,045.01 4,885.91 -1,762.33 -4,496.55 5,928,197.93 476,397.54 3.00 -3,193.96 MWD+IFR-AK-CAZ-SC(3) 7,637.54 51.57 285.38 5,101.79 4,942.69 -1,744.75 -4,567.66 5,928,215.69 476,326.48 2.89 -3,201.76 MVVD+IFR-AK-CAZ-SC(3) 7,731.01 52.60 289.78 5,159.25 5,000.15 -1,722.47 -4,637.92 5,928,238.14 476,256.29 3.87 -3,204.85 MWD+IFR-AK-CAZ-SC(3) 7,823.31 53.12 292.34 5,214.98 5,055.88 -1,696.03 -4,706.57 5,928,264.76 476,187.71 2.28 -3,203.49 MWD+IFR-AK-CAZ-SC(3) 12/14/2016 8.57'15AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Weil; 2S-13 North Reference: True Wefibore: 2S-1 3A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,915.39 5445 296.32 5,269.39 5,110.29 -1,665.41 -4,774.23 5,928,295.54 476,12014 3.77 -3,197.86 MWD+IFR-AK-CAZ-SC(3) 8,007.47 55.41 299.86 5,322.31 5,163.21 -1,629.92 -4,840.69 5,928,331.19 476,053.77 3.31 -3,187.24 MWD+IFR-AK-CAZSC(3) 8,100.49 55.39 303.20 5,375.14 5,216.04 -1,589.89 -4,905.94 5,928,371.39 475,988.63 2.96 -3,171.94 MWD+IFR-AK-CAZSC(3) 8,193.07 55.44 306.84 5,427.71 5,268.61 -1,546.17 -4,968.34 5,928,415.27 475,926.35 3.24 -3,152.19 MWD+IFR-AK-CAZ-SC(3) 8,286.09 55.80 309.81 5,480.24 5,321.14 -1,498.56 -5,028.55 5,928,463.02 475,866.26 2.66 -3,128.06 MWD+IFR-AK-CAZSC(3) 8,380.27 57.04 309.97 5,532.33 5,373.23 -1,448.24 -5,088.76 5,928,513.48 475,806.19 1.32 -3,101.36 MWD+IFR-AK-CAZ-SC(3) 8,473.31 56.71 309.14 5,583.17 5,424.07 -1,398.62 -5,148.83 5,928,563.25 475,746.25 0.83 -3,075.28 MWD+IFR-AK-CAZ-SC(3) 8,564.64 55.84 310.08 5,633.88 5,474.78 -1,350.20 -5,207.35 5,928,611.82 475,687.86 1.28 -3,049.79 MWD+IFR-AK-CAZ-SC(3) 8,659.27 55.94 311.96 5,686.95 5,527.85 -1,298.78 -5,266.46 5,928,663.38 475,628.88 1.65 -3,021.69 MWD+IFR-AK-CAZSC(3) 8,752.97 57.18 315.11 5,738.59 5,579.49 -1,244.92 -5,323.12 5,928,717.38 475,572.37 3.10 -2,990.46 MWD+IFR-AK-CAZSC(3) 8,847 00 58.26 317.39 5,788.82 5,629.72 -1,187.50 -5,378.08 5,928,774.93 475,517.56 2.35 -2,955.29 INC+TREND(4) 10-3/4"x 13-1/2"-Top of 10-3/4"casing window 8,867.00 60.11 316.14 5,799.06 5,639.96 1,174.99 -5,389.85 5,928,787.47 475,505.82 10.69 -2,947.56 INC+TREND(4) 8,938.22 60.40 318.61 5,834.40 5,675.30 -1,129.49 -5,431.72 5,928,833.07 475,464.07 3.04 -2,919.13 INC+TREND(4) 9,033.16 61.50 321.89 5,880.51 5,721.41 -1,065.69 -5,484.77 5,928,897.00 475,411.19 3.23 -2,877.32 INC+TREND(4) 9,128.47 63.09 325.16 5,924.83 5,765.73 -997.84 5,534.90 5,928,964.97 475,361.23 3.47 -2,830.71 INC+TREND(4) 9,224.66 63.51 328.41 5,968.06 5,808.96 -925.95 -5,581.96 5,929,036.97 475,314.36 3.05 -2,779.26 INC+TREND(4) 9,318.30 62.62 331.53 6,010.48 5,851.38 -853.70 -5,623.74 5,929,109.32 475,272.77 3.12 -2,725.65 M1ND+IFR-AK-CAZSC(5) 9,375.23 63.12 332.63 6,036.44 5,877.34 -808.93 -5,647.46 5,929,154.15 475,249.16 1.93 -2,691.69 MWD+IFR-AK-CAZ-SC(5) 9,412.83 63.99 333.29 6,053.19 5,894.09 -778.94 -5,662.77 5,929,184.17 475,233.93 2.80 -2,668.75 MWD+IFR-AK-CAZ-SC(5) 9,461.94 65.63 334.82 6,074.09 5,914.99 -738.98 -5,682.21 5,929,224.17 475,214.60 4.37 -2,637.85 MWD+IFR-AK-CAZ-SC(5) 9,507.98 65.70 334.76 6,093.06 5,933.96 -701.03 -5,700.07 5,929,262.17 475,196.83 0.19 -2,608.29 MWD+IFR-AK-CAZSC(5) 9,602.61 66.32 333.71 6,131.54 5,972.44 -623.17 -5,737.66 5,929,340.11 475,159.45 1.21 -2,547.98 MWD+IFR-AK-CAZ-SC(5) 9,647.82 66.88 333.74 6,149.49 5,990.39 -585.97 -5,756.02 5,929,377.36 475,141.18 1.24 -2,519.30 MWD+IFR-AK-CAZSC(5) 9,696.77 67.55 333.33 6,168.45 6,009.35 -545.57 -5,776.14 5,929,417.81 475,121.17 1.57 -2,488.22 M1ND+IFR-AK-CAZSC(5) 9,791.94 67.87 336.22 6,204.55 6,045.45 -465.92 -5,813.66 5,929,497.55 475,083.85 2.83 -2,426.20 MWD+IFR-AK-CAZSC(5) 9,886.71 68.93 339.38 6,239.45 6,080.35 -384.34 -5,846.94 5,929,579.19 475,050.78 3.30 -2,360.93 MWD+IFR-AK-CAZSC(5) 9,981.86 71.62 341.84 6,271.56 6,112.46 -299.87 -5,876.65 5,929,663.74 475,021.28 3.73 -2,291.72 MVVD+IFR-AK-CAZ-SC(5) 10,076.71 74.36 344.43 6,299.31 6,140.21 -213.08 -5,902.95 5,929,750.58 474,995.21 3.89 -2,219.16 MWD+IFR-AK-CAZSC(5) 10,171.00 78.01 345.70 6,321.83 6,162.73 -124.63 -5,926.53 5,929,839.09 474,971.85 4.09 -2,144.10 MWD+IFR-AK-CAZ-SC(5) 10,265.91 81.96 347.61 6,338.33 6,179.23 -33.71 -5,948.09 5,929,930.05 474,950.53 4.61 -2,066.04 MWD+IFR-AK-CAZSC(5) 10,350.09 85.54 348.73 6,347.49 6,188.39 48.18 -5,965.24 5,930,011.97 474,933.59 4.45 -1,994.95 MWD+IFR-AK-CAZSC(5) 10,410.00 87.66 350.32 6,351.05 6,191.95 106.99 -5,976.11 5,930,070.80 474,922.87 4.42 -1,943.41 MWD+IFR-AK-CAZ-SC(6) 75/8"x 9-7/8" 10,439.96 88.72 351.12 6,351.99 6,192.89 136.54 -5,980.93 5,930,100.36 474,918.12 4.42 -1,917.30 MWD+IFR-AK-CAZ-SC(6) 10,535.42 91.10 353.56 6,352.14 6,193.04 231.13 -5,993.66 5,930,194.98 474,905.63 3.57 -1,832.76 MWD+IFR-AK-CAZSC(6) 10,629.83 92.61 355.61 6,349.09 6,189.99 325.06 -6,002.56 5,930,288.92 474,896.97 2.70 -1,747.54 MWD+IFR-AK-CAZSC(6) 10,724.25 92.92 0.19 6,344.53 6,185.43 419.29 -6,006.02 5,930,383.14 474,893.75 4.86 -1,660.18 MWD+IFR-AK-CAZSC(6) 10,819.52 93.12 3.70 6,339.51 6,180.41 514.35 -6,002.79 5,930,478.19 474,897.22 3.69 -1,569.74 MWD+IFR-AK-CAZSC(6) 10,913.73 92.54 6.90 6,334.86 6,175.76 608.03 -5,994.10 5,930,571.84 474,906.15 3.45 -1,478.74 MWD+IFR-AK-CAZ-SC(6) 12/14/2016 8:57'15AM Page 5 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,008.58 91.57 11.24 6,331.45 6,172.35 701.61 -5,979.16 5,930,665.37 474,921.32 4.69 -1,385.69 MWD+IFR-AK-CAZ-SC(6) 11,103.97 91.78 14.68 6,328.66 6,169.56 794.52 -5,957.78 5,930,758.22 474,942.94 3.61 -1,291.07 MWD+IFR-AK-CAZ-SC(6) 11,198.72 91.89 18.27 6,325.63 6,166.53 885.32 -5,930.92 5,930,848.94 474,970.02 3.79 -1,196.57 MWD+IFR-AK-CAZ-SC(6) 11,293.57 92.68 19.08 6,321.85 6,162.75 975.10 -5,900.58 5,930,938.63 475,000.59 1.19 -1,101.82 MWD+IFR-AK-CAZ-SC(6) 11,388.82 92.12 18.72 6,317.86 6,158.76 1,065.14 -5,869.75 5,931,028.58 475,031.64 0.70 -1,006.67 MWD+IFR-AK-CAZ-SC(6) 11,483.52 92.63 18.77 6,313.93 6,154.83 1,154.74 -5,839.35 5,931,118.10 475,062.27 0.54 -912.08 MWD+IFR-AK-CAZ-SC(6) 11,577.75 90.23 19.57 6,311.58 6,152.48 1,243.71 -5,808.42 5,931,206.98 475,093.42 2.68 -817.89 MWD+IFR-AK-CAZ-SC(6) 11,673.11 89.06 19.46 6,312.17 6,153.07 1,333.59 -5,776.56 5,931,296.77 475,125.50 1.23 -722.54 MVVD+IFR-AK-CAZ-SC(6) 11,767.34 89.06 18.28 6,313.72 6,154.62 1,422.74 -5,746.09 5,931,385.83 475,156.19 1.25 -628.34 MWD+IFR-AK-CAZ-SC(6) 11,862.17 90.17 17.52 6,314.36 6,155.26 1,512.97 -5,716.94 5,931,475.99 475,185.56 1.42 -533.58 MWD+IFR-AK-CAZ-SC(6) 11,957.60 90.48 16.29 6,313.81 6,154.71 1,604.28 -5,689.20 5,931,567.21 475,213.54 1.33 -438.29 MWD+IFR-AK-CAZ-SC(6) 12,051.62 90.34 14.65 6,313.14 6,154.04 1,694.88 -5,664.12 5,931,657.74 475,238.84 1.75 -344.57 MWD+IFR-AK-CAZ-SC(6) 12,146.27 90.65 13.51 6,312.32 6,153.22 1,786.69 -5,641.09 5,931,749.48 475,262.10 1.25 -250.43 MWD+IFR-AK-CAZ-SC(6) 12,240.60 90.72 12.99 6,311.20 6,152.10 1,878.50 -5,619.48 5,931,841.23 475,283.95 0.56 -156.76 MWD+IFR-AK-CAZ-SC(6) 12,334.63 91.10 12.43 6,309.70 6,150.60 1,970.21 -5,598.79 5,931,932.88 475,304.86 0.72 -63.51 MWD+IFR-AK-CAZ-SC(6) 12,429.40 91.23 14.01 6,307.78 6,148.68 2,062.45 -5,577.12 5,932,025.05 475,326.76 1.67 30.58 MWD+IFR-AK-CAZ-SC(6) 12,523.32 90.61 14.69 6,306.27 6,147.17 2,153.42 -5,553.85 5,932,115.96 475,350.26 0.98 124.03 MVVD+IFR-AK-CAZ-SC(6) 12,617.71 90.99 15.51 6,304.95 6,145.85 2,244.55 -5,529.26 5,932,207.01 475,375.08 0.96 218.06 MWD+IFR-AK-CAZ-SC(6) 12,713.41 90.75 15.71 6,303.50 6,144.40 2,336.71 -5,503.51 5,932,299.09 475,401.06 0.33 313.47 MWD+IFR-AK-CAZ-SC(6) 12,807.98 91.27 16.49 6,301.83 6,142.73 2,427.55 -5,477.29 5,932,389.86 475,427.51 0.99 407.81 MWD+IFR-AK-CAZ-SC(6) 12,903.10 91.30 16.20 6,299.70 6,140.60 2,516.80 -5,450.53 5,932,481.04 475,454.50 0.31 502.71 MWD+IFR-AK-CAZ-SC(6) 12,997.68 91.71 16.65 6,297.21 6,138.11 2,609.49 -5,423.80 5,932,571.65 475,481.46 0.64 597.07 MWD+IFR-AK-CAZ-SC(6) 13,092.51 91.85 16.59 6,294.27 6,135.17 2,700.32 -5,396.68 5,932,662.40 475,508.79 0.16 691.69 MWD+IFR-AK-CAZ-SC(6) 13,187.36 91.09 14.95 6,291.83 6,132.73 2,791.56 -5,370.92 5,932,753.57 475,534.79 1.91 786.25 MWD+IFR-AK-CAZ-SC(6) 13,282.41 91.54 14.65 6,289.65 6,130.55 2,883.43 -5,346.64 5,932,845.37 475,559.29 0.57 880.88 MWD+IFR-AK-CAZ-SC(6) 13,376.96 91.68 13.95 6,287.00 6,127.90 2,975 02 -5,323.30 5,932,936.88 475,582.87 0.75 974.93 MWD+IFR-AK-CAZ-SC(6) 13,472.42 91.65 13.72 6,284.22 6,125.12 3,067.67 -5,300.48 5,933,029.47 475,605.92 0.24 1,069.80 MWD+IFR-AK-CAZ-SC(6) 13,567.08 91.85 12.99 6,281.33 6,122.23 3,159.73 -5,278.63 5,933,121.46 475,628.00 0.80 1,163.77 MVVD+IFR-AK-CAZ-SC(6) 13,661.67 91.92 13.17 6,278.22 6,119.12 3,251.81 -5,257.23 5,933,213.48 475,649.63 0.20 1,257.62 M1AID+IFR-AK-CAZ-SC(6) 13,756.58 91.72 14.02 6,275.21 6,116.11 3,344.02 -5,234.93 5,933,305.62 475,672.16 0.92 1,351.89 MWD+IFR-AK-CAZ-SC(6) 13,851.57 91.04 14.42 6,272.92 6,113.82 3,436.07 -5,211.61 5,933,397.60 475,695.71 0.83 1,446.37 MWD+IFR-AK-CAZ-SC(6) 13,945.61 88.46 14.61 6,273.33 6,114.23 3,527.10 -5,188.04 5,933,488.56 475,719.51 2.75 1,539.97 MWD+IFR-AK-CAZ-SC(6) 14,039.92 86.30 13.63 6,277.64 6,118.54 3,618.46 -5,165.06 5,933,579.85 475,742.72 2.51 1,633.68 MWD+IFR-AK-CAZ-SC(6) 14,134.35 87.29 13.68 6,282.92 6,123.82 3,710.07 -5,142.80 5,933,671.41 475,765.21 1.05 1,727.39 MWD+IFR-AK-CAZ-SC(6) • 14,229.07 87.22 13.73 6,287.46 6,128.36 3,801.99 -5,120.38 5,933,763.26 475,787.85 0.09 1,821.43 MWD+IFR-AK-CAZ-SC(6) 14,323.19 87.19 13.00 6,292.04 6,132.94 3,893.45 -5,098.65 5,933,854.65 475,809.81 0.78 1,914.80 MWD+IFR-AK-CAZ-SC(6) 14,417.40 88.04 13.48 6,295.97 6,136.87 3,985.08 -5,077.10 5,933,946.22 475,831.60 1.04 2,008.28 MWD+IFR-AK-CAZ-SC(6) 14,512.01 88.42 14.13 6,298.89 6,139.79 4,076.91 -5,054.53 5,934,037.98 475,854.40 0.80 2,102.29 MWD+IFR-AK-CAZ-SC(6) 14,606.89 87.98 15.06 6,301.87 6,142.77 4,168.68 -5,030.63 5,934,129.68 475,878.52 1.08 2,196.70 MWD+IFR-AK-CAZ-SC(6) 14,701.10 88.06 15.99 6,305.12 6,146.02 4,259.40 -5,005.43 5,934,220.33 475,903.95 0.99 2,290.57 MWD+IFR-AK-CAZ-SC(6) 12/14/2016 8:57,15AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 14,796.86 90.15 16.94 6,306 62 6,147.52 4,351.21 -4,978.30 5,934,312.06 475,931 32 2.40 2,386.13 MWD+IFR-AK-CAZ-SC(6) 14,890.11 89.90 18.40 6,306.58 6,147.48 4,440.06 -4,949.99 5,934,400.83 475,959.84 1.59 2,479.30 MWD+IFR-AK-CAZ-SC(6) 14,985.25 90.40 17.40 6,306.33 6,147.23 4,530.59 -4,920.75 5,934,491.28 475,989.31 1.18 2,574.37 MWD+IFR-AK-CAZ-SC(6) 15,081.04 92.14 18.38 6,304.21 6,145.11 4,621.73 -4,891.34 5,934,582.33 476,018.95 2.08 2,670.07 MWD+IFR-AK-CAZ-SC(6) 15,176.99 91.99 19.58 6,300.75 6,141.65 4,712.40 -4,860.15 5,934,672.91 476,050.37 1.26 2,765.94 MVVD+IFR-AK-CAZ-SC(6) 15,266.87 92.23 20.48 6,297.44 6,138.34 4,796.78 -4,829.39 5,934,757.21 476,081.34 1.04 2,855.76 M1ND+IFR-AK-CAZ-SC(6) 15,360.63 91.75 19.36 6,294.18 6,135.08 4,884.88 -4,797.46 5,934,845.22 476,113.48 1.30 2,949.46 MWD+IFR-AK-CAZ-SC(6) 15,452.95 91.92 17.63 6,291.23 6,132.13 4,972.38 -4,768.19 5,934,932.64 476,142.97 1.88 3,041.69 MWD+IFR-AK-CAZ-SC(6) 15,545.52 91.58 15.86 6,288.40 6,129.30 5,060.98 -4,741.53 5,935,021.16 476,169.85 1.95 3,134.07 MWD+IFR-AK-CAZ-SC(6) 15,638.03 91.37 14.43 6,286.02 6,126.92 5,150.25 -4,717.37 5,935,110.36 476,194.23 1.56 3,226.21 MWD+IFR-AK-CAZ-SC(6) 15,731.19 91.68 13.56 6,283.54 6,124.44 5,240.61 -4,694.85 5,935,200.65 476,216.98 0.99 3,318.83 MWD+IFR-AK-CAZ-SC(6) 15,823.03 92.33 12.64 6,280.33 6,121.23 5,330.00 -4,674.05 5,935,289.98 476,238.01 1.23 3,409.95 MWD+IFR-AK-CAZ-SC(6) 15,914.11 91.82 12.39 6,277.03 6,117.93 5,418.86 -4,654.33 5,935,378.78 476,257.96 0.62 3,500.19 MWD+IFR-AK-CAZ-SC(6) 16,007.20 92.07 13.43 6,273.87 6,114.77 5,509.54 -4,633.54 5,935,469.40 476,278.97 1.15 3,592.51 MWD+IFR-AK-CAZ-SC(6) 16,097.95 90.35 14.16 6,271.95 6,112.85 5,597.65 -4,611.91 5,935,557.45 476,300.82 2.06 3,682.71 MVVD+IFR-AK-CAZ-SC(6) 16,189.55 91.47 15.39 6,270.50 6,111.40 5,686.21 -4,588.55 5,935,645.94 476,324.40 1.82 3,773.91 MWD+IFR-AK-CAZ-SC(6) 16,281.22 91.82 18.29 6,267.86 6,108.76 5,773.90 -4,562.01 5,935,733.55 476,351.16 3.19 3,865.40 MWD+IFR-AK-CAZ-SC(6) 16,372.57 91.61 20.89 6,265.13 6,106.03 5,859.92 -4,531.40 5,935,819.48 476,381.99 2.85 3,956.69 MWD+IFR-AK-CAZ-SC(6) 16,465.96 91.75 21.04 6,262.39 6,103.29 5,947.09 -4,498.00 5,935,906.56 476,415.61 0.22 4,050.03 M1ND+IFR-AK-CAZ-SC(6) 16,557.37 91.99 21.05 6,259.41 6,100.31 6,032.36 -4,465.19 5,935,991.74 476,448.63 0.26 4,141 38 MWD+IFR-AK-CAZ-SC(6) 16,649.73 91.96 20.73 6,256.23 6,097.13 6,118.59 -4,432.27 5,936,077.88 476,481.76 0.35 4,233.67 MWD+IFR-AK-CAZ-SC(6) 16,742.46 91.34 20.53 6,253.56 6,094.46 6,205.34 -4,399.62 5,936,164.54 476,514.63 0.70 4,326.36 MWD+IFR-AK-CAZ-SC(6) 16,833.45 91.20 21.13 6,251.54 6,092.44 6,290.36 -4,367.27 5,936,249.47 476,547.19 0.68 4,417.31 MWD+IFR-AK-CAZ-SC(6) 16,856.69 91.34 21.19 6,251.02 6,091.92 6,312.03 -4,358.88 5,936,271.11 476,555.63 0.66 4,440.54 MWD+IFR-AK-CAZ-SC(6) 16,907.00 91.34 21.19 6,249.85 6,090.75 6,358.93 -4,340.70 5,936,317.96 476,573.93 0.00 4,490.83 PROJECTED to TD 4 112"x 63/4" 16,917.00 91.34 21.19 6,249.61 6,090.51 6,368 25 -4,337.09 5,936,32727 476,577.56 0.00 4,500.82 PROJECTED to TD 12/14/2018 8:57:15AM Page 7 COMPASS 5000.1 Build 74 Cement Detail Report gra 2S-13 ConocdPhitlips String: Conductor Cement Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 10/13/2015 09:45 10/13/2015 15:00 2S-13 Comment CH2MHill drilled 42"hole to 80'below ground level,set 20"78.67#APISL Grade B Insulated Conductor.SLB cemented in two stages with 59.8bbl 15.7ppg Arctic Set 1 cement.Sealed Pan Cellar is 5'deep,6'wide. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Tack conductor in place 85.0 107.5 No 0.0 No No Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 2 2 86.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 10.3 bbl Arctic Set 1 Cement slurry at 15.7ppg,70°F slurry temp, 18°F ambient temp,60°F water temp.CIP @ 10:15 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Conductor cement 80.0 120.0 60 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 15.70 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement to surface 27.5 85.0 No No No Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 48.5 bbl Arctic Set 1 Cement slurry at 15.7ppg,70°F slurry temp, 18°F ambient temp,60°F water temp.Cement in place at 15:00 hrs. TOTAL 59.8bbl pumped Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Conductor cement 0.0 80.0 120 Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/23/2017 Cement Detail Report 2S-13 k3.. ConocoPhillips , rl.:ska String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/3/2015 10:15 12/3/2015 15:45 2S-13 Comment Pump 5 bbls of fresh water&PT lines to 3500 psi.Pump 20 bbls 8.3 ppg CW-100,4 bpm,150 psi.Pump 100 bbls of 10.5 ppg MPII w/red dye at 3.5 bpm, 150 psi.Drop bottom plug&pump 496.5 bbls of 11.0 ppg Lead Cement at 6.5 bpm,350 psi.Pump 79 bbls of 12.0 ppg Tail Cement at 6 bpm,450 psi.Drop top plug &kick out with 10 bbls of fresh H2O at 5 bpm, 160 psi.Swap to rig&displace cement with 10.1 ppg mud at 5.5 bpm,700 psi.Bump plug w/3998 stks,pressure up to 1200 psi&hold for 5 min. Check floats, Floats not holding.Shut in and hold 100 psi.CIP at 15:45 hrs.Total of 282 bbls of cement returns to surface. Flow line packed off at 156 bbls of displacement.Take returns to cellar Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 29.9 2,850.0 Yes 282.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 5 6 700.0 1,200.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls of fresh water&PT lines to 3500 psi.Pump 20 bbls 8.3 ppg CW-100,4 bpm, 150 psi. Pump 100 bbls of 10.5 ppg MPII w/red dye at 3.5 bpm, 150 psi. Drop bottom plug&pump 496.5 bbls of 11.0 ppg Lead Cement at 6.5 bpm,350 psi.Pump 79 bbls of 12.0 ppg Tail Cement at 6 bpm,450 psi.Drop top plug &kick out with 10 bbls of fresh H2O at 5 bpm, 160 psi.Swap to rig&displace cement with 10.1 ppg mud at 5.5 bpm,700 psi.Bump plug w/3998 stks,pressure up to 1200 psi&hold for 5 min.Check floats, Floats not holding.Shut in and hold 100 psi.CIP at 15:45 hrs.Total of 282 bbls of cement returns to surface.Flow line packed off at 156 bbls of displacement.Take returns to cellar Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 29.9 1,954.0 1,460 LiteCRETE 496.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,954.0 2,850.0 278 LiteCRETE 79.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.67 5.01 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Additive Type Concentration Cone Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type 'Concentration 'Cone Unit label Gas Block D500 0.75 gal/sx Page 1/1 Report Printed: 1/23/2017 Cement Detail Report t 2S-13 ConocoPhillips . String: Liner Cement Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 12/13/2015 12:00 12/13/2015 16:20 2S-13 Comment PJSM for cementing 10.75"liner.Pump 5 bbls of CW-100&PT lines to 400/4000 psi for 5 min.Pump 35 bbls of CW-100 @ 4 bpm,500 psi.Batch up mud push. Pump 40 bbls of 11.5 ppg MPII @ 5 bpm,450 psi.Batch up cement.Pump 320 bbls of 15.8 ppg cement @ 5.5 bpm,300 psi.Kick out top plug with 10 bbls of H20.Swap to rig pumping 10.0 ppg mud to displace.Pump 21 bbls to©6 bpm=140 psi,slow to 3 bpm=75 psi,observe latch up with pressure increase to 650 psi.Continue pumping 6.5 bpm=400 psi.Observe cement lift with pressure increasing to 1640 psi.Started seeing losses @ 555 bbls into displacement observed losses.Slowed pump to 3 bpm=1100 psi.Bump the plug with 641 bbls,pressure up to 1700 psi.Hold pressure for 5 min&bleed off.Floats good.CIP @ 16:20 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Liner Cement 5,840.0 9,329.0 No Yes No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 6 1,100.0 1,700.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,840.0 9,329.0 1,535 G 320.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 3.25 15.80 5.60 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.15 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.6 gal/sx Page 1/1 Report Printed: 1/23/2017 Cement Detail Report 0 2S-13 ConocoPhillips String: Cement Plug -Abandon 2S-13 PB1 Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug-Abandon 2S-13 PB1 12/17/2015 18:15 12/17/2015 19:30 2S-13 Comment Batch up&pump 5 bbls of 13.0 ppg MPII to flood lines.PT lines 400/4000 psi. Pump 25 bbls of 13.0 ppg MPII @ 3.4 bpm,460 psi.Load wiper ball in pipe& batch up cement.Pump 70 bbls of 15.8 ppg cement w/1.5 ppb CemNet @ 4.4 bpm,430-100 psi. Pump 5.3 bbls of 13.7 MPII @ 3.5 bpm,30 psi.Swap to rig& displace with 156 bbls of 11.9 ppg mud @ 4.5 bpm, 125-780 psi.CIP 19:28 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Plug 9,710.0 10,303.0 No No Yes Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 780.0 No No Tagged Depth(ftKB) 'Tag Method 'Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Plug back Intermediate#2 pilot hole. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 9,710.0 10,303.0 338 G 70.0 Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 94.3 6.20 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 1/1 Report Printed: 1/23/2017 • • Cement Detail Report 2S-13 Conoco Phillips String: Cement Plug -Kickoff for 2S-13 intrm s... Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug-Kickoff for 2S-13 intrm section 12/17/2015 23:30 12/18/2015 00:40 2S-13 Comment Pump 31 bbls 13.0 ppg MPII @ 4.4 bpm,575 psi.Shut down to batch up cement,load wiper ball in pipe.Pump 66 bbls of 17.0 ppg cement w/1.5 ppb CemNet @ 4 bpm,475-40 psi.Pump 7 bbls of 13.0 ppg MPII @ 3 bpm, 10 psi.Swap to rig to displace 143 bbls with 11.9 ppg mud @ 4.5 bpm, 120-800 psi.CIP @ 00:40 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Plug 9,117.0 9,710.0 No No Yes Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 5 5 800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 9,131.0 Drill Bit 9,710.0 9 7/8 Comment KOP for intermediate#2. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 9,117.0 9,710.0 371 G 66.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.00 3.86 17.00 175.0 7.40 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.9 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 1/1 Report Printed: 1/23/2017 Cement Detail Report 2S-13 • conocoPhjilips 140 String: Intermediate#3 Casing Cement Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate#3 Casing Cement 12/27/2015 03:00 12/27/2015 07:30 2S-13 Comment PJSM;line up to cementers&pump 5 bbls of CW-100.Pressure test lines 500/3500 psi for 5 min.Pump 5 bbls of CW-100,3 bpm,540 psi. Pump 40 bbls of 12.5 ppg MPII at 3 bpm,540 psi.Load wiper plug in pipe.Pump 72 bbls of 15.8 ppg cement slurry w/2 lb/bbl CemNet at3 bpm,275 psi.Load shut off plug in pipe. Pump 10 bbls of H20.Swap to rig&displace with 460 bbls of 11.8+ppg mud at 3 bpm,250-600 psi.Bump plug&pressure up to 1200 psi&hold for 5 min. CIP 07:30 hrs. While chasing the plug with the rig pump the pits received an average of 50%returns from 0 to 420 bbls away.Returns steadily increased the last 40 bbls and full returns were achieved the last 20 bbls as the cement came up the annulus.400 psi lift pressure was observed. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 9,167.0 10,444.0 No Yes Yes Cement Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 600.0 1,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM;line up to cementers&pump 5 bbls of CW-100. Pressure test lines 500/3500 psi for 5 min. Pump 5 bbls of CW-100,3 bpm,540 psi.Pump 40 bbls of 12.5 ppg MPII at 3 bpm,540 psi.Load wiper plug in pipe.Pump 72 bbls of 15.8 ppg cement slurry w/2 lb/bbl CemNet at3 bpm,275 psi. Load shut off plug in pipe.Pump 10 bbls of H20.Swap to rig&displace with 460 bbls of 11.8+ppg mud at 3 bpm,250-600 psi.Bump plug&pressure up to 1200 psi&hold for 5 min. CIP 07:30 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 9,167.0 10,444.0 348 G 72.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 97.6 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Page 1/1 Report Printed: 1/23/2017 t Cement Detail Report 2S-13 ConocoPhillips String: Abandonment Cement Plug Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Abandonment Cement Plug 11/2/2016 06:45 11/2/2016 08:00 2S-13L1 Comment SLB pump 2 bbls 12.5 ppg mudpush.Shut in and pressure test cement lines to 4000 psi-good test.Continue pumping 8 bbls 12.5 ppg mudpush at 2.5 bpm, 1308 psi,21.7 bbls 15.8ppg cement at 2.8 bpm, 1217 psi,and 3.1 bbls 12.5 ppg mudpush at 2.2 bpm,994 psi.Clear lines to rig floor with 1.5 bbls water.Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi.Hold 800 psi backpressure with rig choke throughout job.Strip down and sting into retainer. Bleed off IA pressure and open annular-monitor for leaks throughout job. Pump 27.8 bbls w/rig at 3 bpm, ICP 955 psi,FCP 1177 psi,squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer.Sting out of retainer,lay out single, and POOH 2 x stands at 1000 ft/hr to 9609'.Left 4.9 bbls of 15.8ppg cement in hole above retainer.Estimated TOC @ 9704'. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Abandonment Cement Isolate formation and 9,704.0 10,186.0 No 0.0 No No Plug abandon laterals Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 3 3 1,177.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Squeezed 16.8 bbls cement below retainer and left 4.9 bbls above. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,903.0 8,373.0 G 58.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 1/23/2017 ,,Z • Cement Detail Report 2S-13 ConocoPhillips 0 String: Abandonment Cement Plug Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Abandonment Cement Plug 11/2/2016 06:45 11/2/2016 08:00 2S-13L1 Comment SLB pump 2 bbls 12.5 ppg mudpush.Shut in and pressure test cement lines to 4000 psi-good test.Continue pumping 8 bbls 12.5 ppg mudpush at 2.5 bpm, 1308 psi,21.7 bbls 15.8ppg cement at 2.8 bpm, 1217 psi,and 3.1 bbls 12.5 ppg mudpush at 2.2 bpm,994 psi.Clear lines to rig floor with 1.5 bbls water.Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi.Hold 800 psi backpressure with rig choke throughout job.Strip down and sting into retainer.Bleed off IA pressure and open annular-monitor for leaks throughout job.Pump 27.8 bbls w/rig at 3 bpm, ICP 955 psi,FCP 1177 psi,squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer.Sting out of retainer,lay out single,and POOH 2 x stands at 1000 ft/hr to 9609'.Left 4.9 bbls of 15.8ppg cement in hole above retainer.Estimated TOC @ 9704'. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Abandonment Cement Isolate formation and 9,704.0 10,186.0 No 0.0 No No Plug abandon laterals Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 3 3 1,177.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Squeezed 16.8 bbls cement below retainer and left 4.9 bbls above. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,903.0 8,373.0 G 58.8 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/23/2017 • Cement • Detail Report 2S-13 Conocd`f'hilliip1 0 s <.. String: 7 5/8 Liner Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7 5/8 Liner 11/14/2016 11:30 11/14/2016 13:00 2S-13L1 Comment Schlumberger pumped 5 Bbls water.Tested lines to 4000 psi.Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet.4.4 to 6 BPM.Dart launch confirmed for both Darts.Pumped 10 Bbls Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls.Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 7 5/8 Liner Cement Liner 8,687.0 10,403.0 Yes Yes Yes Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 838.0 1,196.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Schlumberger pumped 5 Bbls water.Tested lines to 4000 psi.Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet.4.4 to 6 BPM. Dart launch confirmed for both Darts.Pumped 10 Bbls Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls.Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 8,687.0 10,403.0 G 92.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 Additives Additive Type Concentration Conc Unit label 7 /� 4"1 < a, I ' • � i r�� 5 I/ z 7- Page 1/1 Report Printed: 1/23/2017 • n--I S A- Prb 2 I(0 04o Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Tuesday, January 17, 2017 9:17 AM To: Herrera, Matthew F (DOA) f` Cc: Regg,James B (DOA); NSK Fieldwide Operations Supt Subject: RE:January 2017 SVS Testing Notification Attachments: 2S-13A deficiency rpt Wellhouse sign to AOGCC 01-17.pdf Matt-2S-13A well house sign has been corrected with the right PTD#. Township, Range and API #are also correct. Enclosed is the deficiency report and sign photo. Let me know if you need anything else. Darrell Humphrey/ Matthew Raiche Production Engineering Specialist C hi + ps Alaska Ph:907.659.7535 I Pg:924 I Mail: N5K 69 From: Herrera, Matthew F (DOA) [mailto:matthew.herrera@alaska.gov] Sent: Friday,January 13, 2017 8:33 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: Regg,James B (DOA) <jim.regg@alaska.gov> Subject: [EXTERNAL]RE:January 2017 SVS Testing Notification Darrell here is deficiency report for the well house sign on 2S-13A let me know when it has been rectified Thank You 917117 C:fiteiert matthew.herrera@alaska.gov Petroleum Inspector AOGCC 907-953-7966 (Personal cell) 907-448-1227 (Slope cell) 907-659-2714 (Slope office) 1 • J LEA l l7 V I r-11 O a I'% • Oil and Gas Conservation Commission - F-',e---\11-1(11 Deficiency Report , Location: r,i2j� 7. —/3/4f. Date: y PTD: . �� /Dyy- (lzS 51, )w+ti 5(4 Operator: Cfr J Type Inspection: )f )perator Rep: O."(/0,-- 4.1��)' Inspector: .�// °2 a.....---• Position: /thy i---61__Z- / 7 f--e-Ly Op. Phone: 7 ie7- 7z29, Correct by(date): Op. Email: /zipizFollow Up Req'd: • �ti/9�' � ,e I Gr�T�`-ems Detailed Description of Deficiencies Date Corrected 42,E %_, G (r1r 14-4?./( d 2-____-232/ ,V , /e91- /, / 9 4 ._..2Ll/ Z 60 ff Li- .c 5 F- S I tm ti C rz e.g.,- i> '7(_. R e"" `2 C / - /5 - i7 Cep e r Pr r 2 l 6 101-10 ��. __ Attachments: ✓l, (:) -r Ope ator Rep Signatures: �,► .,. - (J AOGCC Inspector *After signing, a copy of thi o is'le Ai- = with the operator. / ow-up Instructions irn a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Correct attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection wa; ormed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"dal the requested and accompanied by justification (Attention: Inspection Supervisor).Documentation of deficiences that are outside iCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. sed 2/2016 h ,...' .,' ' J' ,n.r N' jFt. .-...7-:t ._ .. ' «-.� x ' .Y "«sr r "7"" . - C , '-•d €,.. :' yY .,,,: , .F•,r, x :;:.;z ;,ri . :�:�:•..„. r;r,.^"_ .fir"+'yE.•.: ..qs� , fir "S : � ' % ,• ,W {wr ` s ice? , Y �� „ i f. . •„ .<�,. 3� ,�;,^'�f: 1` i»^%.+; .,, 4. .S . fix.., , z `,, . 4 , ms ; 1fir 'ii , .tX ` ,. , ...... : • y � iYS "di t . , , , �,< 't ` 1'l : � ' T "S` :, ..4 ;c .. , .Hx, 1 Is 1. ,.„ rFz : .,,,,,,,•, • ,• .:•,4,",` i,' , :', r• :•,*: : k.,, JA z w4Y, ''''''''','61:':'''..',' «. >s,i:^;� '' ' , ...= -,,',";,,,',.--:,*•',."..., :X _ .,T „r ;z. ✓ . ,,:,,,,t s• 'n° . ': ,i -..it, z • • y , x«^'wS • x1 `;'4:,--•::' J '%"'„k' aV' ;.�,€"t'a#,w, ` ^� `;'^w. ct- .,.;•, ,'<rtc,`':,.-.;-....,:-,1* „ t • , u�'d4.�`•. • ' Xp �' : � - , ' : � ?It �• + .1,:;:.,-,.:.._,A-.,,...,,,:.",,,.:, �� • ..Y . ', i, � ;s. JA "Wr Sf, :. . y,� „'N i ry ` w, �� 74 .'ti: ',,,;;..-.-----.;7!, ''' -.Ar � ,yLr. .NN'- 'M y'y• � ;:;s ' �. . T':g'% , ' •� ,s. , 1r ".fag`;',2 A'> .A;. „J : a' �7,* 4'.;,:.1,,,':,”. °'A" ,,ti cy:=;;.« <'•r,,".,,. < ' 4;. :.f,, ,. ,,,:, „...:'.. 5 f M n ,s ,.: '"' +::"k- -- `'�_. �� :pk'a 'k _ ',k:•'.c '� t 'z:�.�.,,::;.. ;,;':i,`� t• �:.a'�:.. - K'a-!:',...7.„.••;':,";..„,4 ,, ,A.'' >�F'r:r,,,:1,', �''v„"s..,��°"+,'>. •_ fit5..X, ,`:a,,,• 9'•-` `i.. ',fir «:k..,,,,, ..w�:: '`.:.� "�. .;e. , tt ' t' t4r. Y«" "� C} p, : : kr 3 „ , . . , c ..g.i. , .,... 1 , .. . _ 1 _ .4,....„ ..: ,.. „.•,...,., „e: „:::::,,' ' . " . ;. , '' " 1 ' :A'';. , c y : wry- ' ,,,. :. "'' r.,- 9 ,, ,fir .. ... xwr•3'^MWMMM""„'r^ A w.r..,. 3 ter i 4 �; "i . •, •,ci'laillips .R:r#::a, kir.:‘tti:E•{'permitted 't :.,74,...-;-f r*..•.Y '.'• :ihaut;tiritien a,nsent of ConocoPlulhps E # , • ",> I, t"r f..:4„,,,t: i' et CEIVED 2 1 6 1 04 • JAN 13 71117 2 7 8 7 7 Schlumberger AOGCC Transmittal#: 13JAN17-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery �itK:t2o17 ENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-13A Date Dispatched: 13-Jan-17 Job#: 16AKA0108 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2 MD x x VISION*Service T TVD x x VISION*Service 5"MD VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a)conocophillips.com AlaskaPTSPrintCenterslb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Received By: u 6, - 110 • 21 61 04 27877 RECEIVED NADConversion JAN 13 2017 Kuparuk River Unit Kuparuk 2S Pad A©GC 2S-13A Definitive Survey Report 14 December, 2016 NAD 27 • lik Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-13 Well Position +N/-S 0.00 usft Northing: 5,929,948.70 usft Latitude: 70°13'11.187 N +El-W 0.00 usft Easting: 480,898.09 usft Longitude: 150°9'14.767 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore 2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°l (nT) BGGM2016 12/1/2016 17.71 80.84 57,531 Design 2S-13A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,752.87 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 20.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 94.28 1,295.18 2S-13PB1 Srvy#1-SLB_NSG+Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2: 1,316.39 2,787.14 2S-13PB1 Srvy#2-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:21 2,879.81 8,752.87 2S-13PB1 Srvy#3-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 8,847.00 9,224.66 2S-13A Srvy 1-SLB_INC+Filler(2S-13A INC+TREND Inclinometer+known azi trend 11/10/2016 11:11 9,318.30 10,350.09 2S-13A Srvy 2-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2016 11:2' 10,350.09 16,856.69 2S-13A Srvy 3-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/18/2016 9:48 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,948.70 480,898.09 0.00 0.00 UNDEFINED 94.28 0.03 287.05 94.28 -64.82 0.00 -0.01 5,929,948.70 480,898.08 0.05 0.00 GYD-GC-SS(1) 119.10 0.04 238.86 119.10 -40.00 0.00 -0.03 5,929,948.70 480,898.06 0.11 -0.01 NOT an Actual Survey 20"x 42" 186.46 0.10 201.50 186.46 27.36 -0.06 -0.07 5,929,948.64 480,898.02 0.11 -0.08 GYD-GC-SS(1) 278.50 0.54 204.98 278.50 119.40 -0.53 -0.28 5,929,948.17 480,897.81 0.48 -0.59 GYD-GC-SS(1) 370.52 2.63 196.47 370.48 211.38 -2.95 -1.06 5,929,945.75 480,897.02 2.28 -3.13 GYD-GC-SS(1) 462.15 4.08 197.58 461.95 302.85 -8.07 -2.64 5,929,940.63 480,895.43 1.58 -8.49 GYD-GC-SS(1) 554.04 4.84 198.23 553.56 394.46 -14.87 -4.84 5,929,933.84 480,893.21 0.83 -15.63 GYD-GC-SS(1) 645.95 5.99 202.27 645.06 485.96 -22.99 -7.87 5,929,925.73 480,890.16 1.32 -24.30 GYD-GC-SS(1) 12/14/2016 8:57:15AM Page 2 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual©159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual©159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 737.60 6.53 203.78 736.16 577.06 -32.19 -11.79 5,929,916.55 480,886.22 0.62 -34.28 GYD-GC-SS(1) 829.54 8.48 201.86 827.31 668.21 -43.26 -16.42 5,929,905.48 480,881.56 2.14 -46.27 GYD-GC-SS(1) 922.16 9.80 205.54 918.75 759.65 -56.71 -22.36 5,929,892.05 480,875.59 1.56 -60.94 GYD-GC-SS(1) 1,015.46 11.08 208.23 1,010.51 851.41 -71.78 -30.02 5,929,877.01 480,867.89 1.47 -77.72 GYD-GC-SS(1) 1,107.69 12.93 209.29 1,100.72 941.62 -88.59 -39.27 5,929,860.22 480,858.60 2.02 -96.67 GYD-GC-SS(1) 1,200.16 15.38 208.11 1,190.37 1,031.27 -108.43 -50.11 5,929,840.41 480,847.72 2.67 -119.03 GYD-GC-SS(1) 1,295.18 19.22 206.89 1,281.08 1,121.98 -133.50 -63,12 5,929,815.37 480,834.64 4.06 -147.04 GYD-GC-SS(1) 1,316.39 20.60 207.96 1,301.02 1,141.92 -139.91 -66.45 5,929,808.97 480,831.29 6.73 -154.20 MWD+IFR-AK-CAZ-SC(2) 1,408.27 21.80 208.96 1,386.68 1,227.58 -169.12 -82.29 5,929,779.81 480,815.38 1.36 -187.06 MWD+IFR-AK-CAZ-SC(2) 1,502.81 25.56 213.09 1,473.25 1,314.15 -201.58 -101.93 5,929,747.40 480,795.66 4.34 -224.28 MWD+IFR-AK-CAZ-SC(2) 1,596.76 27.45 217.68 1,557.33 1,398.23 -235.70 -126.24 5,929,713.34 480,771.27 2.97 -264.66 MWD+IFR-AK-CAZ-SC(2) 1,689.53 29.30 221.23 1,638.96 1,479.86 -269.70 -154.27 5,929,679.41 480,743.15 2.70 -306.20 MWD+IFR-AK-CAZ-SC(2) 1,783.35 30.21 225.91 1,720.42 1,561.32 -303.40 -186.36 5,929,645.81 480,710.98 2.66 -348.84 MWD+IFR-AK-CAZ-SC(2) 1,875.34 31.06 226.45 1,799.57 1,640.47 -335.85 -220.19 5,929,613.44 480,677.08 0.97 -390.90 MWD+IFR-AK-CAZ-SC(2) 1,968.32 32.83 229.72 1,878.47 1,719.37 -368.68 -256.80 5,929,580.71 480,640.38 2.66 -434.28 MWD+IFR-AK-CAZ-SC(2) 2,061.97 33.68 233.62 1,956.79 1,797.69 -400.50 -297.08 5,929,549.00 480,600.02 2.46 -477.95 MWD+IFR-AK-CAZ-SC(2) 2,154.77 34.26 235.37 2,033.75 1,874.65 -430.60 -339.29 5,929,519.00 480,557.74 1.23 -520.68 MWD+IFR-AK-CAZ-SC(2) 2,249.17 35.48 238.69 2,111.21 1,952.11 -459.94 -384.57 5,929,489.78 480,512.40 2.39 -563.74 MWD+IFR-AK-CAZ-SC(2) 2,342.07 38.90 240.04 2,185.21 2,026.11 -488.53 -432.89 5,929,461.32 480,464.01 3.78 -607.12 MWD+IFR-AK-CAZ-SC(2) 2,435.49 39.45 242.06 2,257.63 2,098.53 -517.09 -484.53 5,929,432.89 480,412.31 1.49 -651.62 MWD+IFR-AK-CAZ-SC(2) 2,526.64 40.79 245.52 2,327.34 2,168.24 -543.00 -537.21 5,929,407.12 480,359.56 2.85 -693.99 MWD+IFR-AK-CAZ-SC(2) 2,620.76 42.70 247.70 2,397.57 2,238.47 -567.85 -594.73 5,929,382.41 480,301.98 2.55 -737.01 MWD+IFR-AK-CAZ-SC(2) 2,713.46 43.56 247.40 2,465.22 2,306.12 -592.05 -653.30 5,929,358.36 480,243.36 0.95 -779.79 MWD+IFR-AK-CAZ-SC(2) 2,787.14 45.32 247.46 2,517.82 2,358.72 -611.85 -700.94 5,929,338.69 480,195.68 2.39 -814.69 MWD+IFR-AK-CAZ-SC(2) 2,846.60 46.00 247.45 2,559.38 2,400.28 -628.16 -740.21 5,929,322.48 480,156.37 1.14 -843.44 NOT an Actual Survey 13-3/8"x 16" 2,879.61 46.37 247.44 2,582.24 2,423.14 -637.29 -762.21 5,929,313.40 480,134.35 1.14 -859.55 MWD+IFR-AK-CAZ-SC(3) 2,973.48 45.93 246.36 2,647.27 2,488.17 -663.85 -824.47 5,929,287.01 480,072.02 0.95 -905.80 MWD+IFR-AK-CAZ-SC(3) 3,064.84 45.12 245.87 2,711.27 2,552.17 -690.24 -884.08 5,929,260.77 480,012.35 0.97 -950.99 MWD+IFR-AK-CAZ-SC(3) 3,156.72 45.68 246.79 2,775.79 2,616.69 -716.50 -944.00 5,929,234.66 479,952.38 0.94 -996.16 MWD+IFR-AK-CAZ-SC(3) 3,249.58 47.31 247.54 2,839.71 2,680.61 -742.63 -1,006.07 5,929,208.69 479,890.24 1.85 -1,041.94 MWD+IFR-AK-CAZ-SC(3) 3,344.32 50.46 248.03 2,902.00 2,742.90 -769.61 -1,072.14 5,929,181.88 479,824.11 3.35 -1,089.89 MWD+IFR-AK-CAZ-SC(3) 3,437.25 51.28 247.93 2,960.65 2,801.55 -796.64 -1,138.97 5,929,155.03 479,757.22 0.89 -1,138.15 MWD+IFR-AK-CAZ-SC(3) 3,530.59 55.39 247.67 3,016.37 2,857.27 -824.93 -1,208.28 5,929,126.92 479,687.85 4.41 -1,188.43 MWD+IFR-AK-CAZ-SC(3) 3,621.02 56.46 248.04 3,067.04 2,907.94 -853.16 -1,277.65 5,929,098.86 479,618.41 1.23 -1,238.69 MWD+IFR-AK-CAZ-SC(3) 3,714.87 57.86 248.01 3,117.93 2,958.83 -882.67 -1,350.77 5,929,069.54 479,545.22 1.49 -1,291.43 MWD+IFR-AK-CAZ-SC(3) 3,806.95 58.60 248.24 3,166.41 3,007.31 -911.83 -1,423.42 5,929,040.56 479,472.51 0.83 -1,343.68 MWD+IFR-AK-CAZ-SC(3) 3,900.29 62.00 248.65 3,212.65 3,053.55 -941.61 -1,498.82 5,929,010.98 479,397.04 3.66 -1,397.45 MWD+IFR-AK-CAZ-SC(3) 3,994.62 62.42 248.93 3,256.63 3,097.53 -971.80 -1,576.62 5,928,980.99 479,319.18 0.52 -1,452.43 MWD+IFR-AK-CAZ-SC(3) 4,086.87 61.97 248.44 3,299.66 3,140.56 -1,001.46 -1,652.63 5,928,951.52 479,243.09 0.68 -1,506.30 MWD+IFR-AK-CAZ-SC(3) 12/14/2016 8:57:15AM Page 3 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,179.93 61.01 250.91 3,344.09 3,184.99 -1,029.87 -1,729.30 5,928,923.31 479,166.36 2.55 -1.559.22 MWD+IFR-AK-CAZ-SC(3) 4,273.79 60.59 251.46 3,389.88 3,230.78 -1,056.29 -1,806.86 5,928,897.09 479,088.74 0.68 -1,610.57 MWD+IFR-AK-CAZ-SC(3) 4,368.17 60.80 251.48 3,436.07 3,276.97 -1,082.45 -1,884.89 5,928,871.13 479,010.65 0.22 -1,661.84 MWD+IFR-AK-CAZ-SC(3) 4,461.58 61.03 251.32 3,481.48 3,322.38 -1,108.49 -1,962.26 5,928,845.29 478,933.23 0.29 -1,712.77 MWD+IFR-AK-CAZ-SC(3) 4,556.36 61.00 251.15 3,527.41 3,368.31 -1,135.16 -2,040.76 5,928,818.82 478,854.67 0.16 -1,764.68 MWD+IFR-AK-CAZ-SC(3) 4,650.19 61.06 250.63 3,572.86 3,413.76 -1,162.03 -2,118.33 5,928,792.15 478,777.04 0.49 -1,816.46 MWD+IFR-AK-CAZ-SC(3) 4,743.61 60.86 249.57 3,618.21 3,459.11 -1,189.83 -2,195.12 5,928,764.55 478,700.18 1.01 -1,868.85 MWD+IFR-AK-CAZ-SC(3) 4,837.87 60.79 250.20 3,664.16 3,505.06 -1,218.13 -2,272.40 5,928,736.44 478,622.84 0.59 -1,921.88 MWD+IFR-AK-CAZ-SC(3) 4,928.53 61.06 250.33 3,708.21 3,549.11 -1,244.89 -2,346.99 5,928,709.88 478,548.19 0.32 -1,972.53 MWD+IFR-AK-CAZ-SC(3) 5,021.88 61.10 250.12 3,753.36 3,594.26 -1,272.53 -2,423.88 5,928,682.43 478,471.24 0.20 -2,024.81 MWD+IFR-AK-CAZ-SC(3) 5,114.38 60.72 250.05 3,798.33 3,639.23 -1,300.07 -2,499.87 5,928,655.09 478,395.18 0.42 -2,076.67 MWD+IFR-AK-CAZ-SC(3) 5,206.88 60.66 249.61 3,843.61 3,684.51 -1,327.88 -2,575.59 5,928,627.48 478,319.41 0.42 -2,128.70 MWD+IFR-AK-CAZ-SC(3) 5,300.97 60.74 250.17 3,889.66 3,730.56 -1,356.09 -2,652.64 5,928,599.46 478,242.29 0.53 -2,181.56 MWD+IFR-AK-CAZ-SC(3) 5,393.35 60.67 250.09 3,934.86 3,775.76 -1,383.47 -2,728.41 5,928,572.27 478,166.46 0.11 -2,233.21 MWD+IFR-AK-CAZ-SC(3) 5,485.05 60.63 250.62 3,979.80 3,820.70 -1,410.35 -2,803.68 5,928,545.60 478,091.13 0.51 -2,284.21 MWD+IFR-AK-CAZ-SC(3) 5,579.52 60.66 250.87 4,026.11 3,867.01 -1,437.50 -2,881.42 5,928,518.64 478,013.33 0.23 -2,336.31 MWD+IFR-AK-CAZ-SC(3) 5,673.28 60.74 251.47 4,072.00 3,912.90 -1,463.89 -2,958.80 5,928,492.45 477,935.88 0.56 -2,387.58 MWD+IFR-AK-CAZ-SC(3) 5,768.68 60.53 251.29 4,118.78 3,959.68 -1,490.44 -3,037.60 5,928,466.11 477,857.04 0.27 -2,439.47 MWD+IFR-AK-CAZ-SC(3) 5,862.17 60.90 250.91 4,164.51 4,005.41 -1,516.85 -3,114.74 5,928,439.89 477,779.83 0.53 -2,490.68 MWD+IFR-AK-CAZ-SC(3) 5,955.59 60.44 248.47 4,210.28 4,051.18 -1,545.11 -3,191.11 5,928,411.82 477,703.39 2.33 -2,543.35 MWD+IFR-AK-CAZ-SC(3) 6,048.82 60.79 249.67 4,256.03 4,096.93 -1,574.13 -3,266.99 5,928,383.00 477,627.45 1.18 -2,596.57 MWD+IFR-AK-CAZ-SC(3) 6,141.13 60.59 248.07 4,301.22 4,142.12 -1,603.14 -3,342.06 5,928,354.18 477,552.31 1.53 -2,649.51 MWD+IFR-AK-CAZ-SC(3) 6,234.01 60.88 248.38 4,346.62 4,187.52 -1,633.20 -3,417.31 5,928,324.32 477,477.00 0.43 -2,703.49 MWD+IFR-AK-CAZ-SC(3) 6,327.61 60.70 248.15 4,392.30 4,233.20 -1,663.45 -3,493.20 5,928,294.26 477,401.04 0.29 -2,757.88 MWD+IFR-AK-CAZ-SC(3) 6,420.92 60.61 250.20 4,438.03 4,278.93 -1,692.37 -3,569.22 5,928,265.54 477,324.96 1.92 -2,811.05 MWD+IFR-AK-CAZ-SC(3) 6,513.98 58.16 250.88 4,485.42 4,326.32 -1,719.05 -3,644.72 5,928,239.05 477,249.39 2.71 -2,861.95 MWD+IFR-AK-CAZ-SC(3) 6,609.81 58.41 253.51 4,535.80 4,376.70 -1,743.97 -3,722.33 5,928,214.33 477,171.73 2.35 -2,911.91 MWD+IFR-AK-CAZ-SC(3) 6,700.72 58.87 256.33 4,583.12 4,424.02 -1,764.16 -3,797.27 5,928,194.33 477,096.74 2.70 -2,956.51 MWD+IFR-AK-CAZ-SC(3) 6,795.26 59.28 258.89 4,631.71 4,472.61 -1,781.56 -3,876.47 5,928,177.14 477,017.51 2.36 -2,999.95 MWD+IFR-AK-CAZ-SC(3) 6,890.38 58.49 262.31 4,680.88 4,521.78 -1,794.87 -3,956.79 5,928,164.03 476,937.16 3.19 -3,039.92 MWD+IFR-AK-CAZ-SC(3) 6,986.56 57.42 266.31 4,731.92 4,572.82 -1,802.96 -4,037.89 5,928,156.14 476,856.05 3.70 -3,075.27 MWD+IFR-AK-CAZ-SC(3) 7,079.86 56.96 269.00 4,782.48 4,623.38 -1,806.17 -4,116.23 5,928,153.13 476,777.71 2.47 -3,105.08 MWD+IFR-AK-CAZ-SC(3) 7,173.85 56.44 272.56 4,834.10 4,675.00 -1,805.11 -4,194.76 5,928,154.39 476,699.20 3.21 -3,130.94 MWD+IFR-AK-CAZ-SC(3) 7,265.88 55.85 275.87 4,885.38 4,726.28 -1,799.50 -4,270.96 5,928,160.19 476,623.01 3.05 -3,151.74 MWD+IFR-AK-CAZ-SC(3) 7,357.32 55.88 278.70 4,936.70 4,777.60 -1,789.91 -4,346.02 5,928,169.97 476,547.98 2.56 -3,168.39 MWD+IFR-AK-CAZ-SC(3) 7,452.65 55.03 280.27 4,990.75 4,831.65 -1,776.97 -4,423.47 5,928,183.10 476,470.58 1.62 -3,182.73 MWD+IFR-AK-CAZ-SC(3) 7,544.85 52.88 282.42 5,045.01 4,885.91 -1,762.33 -4,496.55 5,928,197.93 476,397.54 3.00 -3,193.96 MWD+IFR-AK-CAZ-SC(3) 7,637.54 51.57 285.38 5,101.79 4,942.69 -1,744.75 -4,567.66 5,928,215.69 476,326.48 2.89 -3,201.76 MWD+IFR-AK-CAZ-SC(3) 7,731.01 52.60 289.78 5,159.25 5,000.15 -1,722.47 -4,637.92 5,928,238.14 476,256.29 3.87 -3,204.85 MWD+IFR-AK-CAZ-SC(3) 7,823.31 53.12 292.34 5,214.98 5,055.88 -1,696.03 -4,706.57 5,928,264.76 476,187.71 2.28 -3,203.49 MWD+IFR-AK-CAZ-SC(3) 12/14/2016 8:57:15AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 •Survey Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 7,915.39 54.45 296.32 5,269.39 5,110.29 -1,665.41 -4,774.23 5,928,295.54 476,120.14 3.77 -3,197.86 MWD+IFR-AK-CAZ-SC(3) 8,007.47 55.41 299.86 5,322.31 5,163.21 -1,629.92 -4,840.69 5,928,331.19 476,053.77 3.31 -3,187.24 MWD+IFR-AK-CAZ-SC(3) 8,100.49 55.39 303.20 5,375.14 5,216.04 -1,589.89 -4,905.94 5,928,371.39 475,988.63 2.96 -3,171.94 MWD+IFR-AK-CAZ-SC(3) 8,193.07 55.44 306.84 5,427.71 5,268.61 -1,546.17 -4,968.34 5,928,415.27 475,926.35 3.24 -3,152.19 MWD+IFR-AK-CAZ-SC(3) 8,286.09 55.80 309.81 5,480.24 5,321.14 -1,498.56 -5,028.55 5,928,463.02 475,866.26 2.66 -3,128.06 MWD+IFR-AK-CAZ-SC(3) 8,380.27 57.04 309.97 5,532.33 5,373.23 -1,448.24 -5,088.76 5,928,513.48 475,806.19 1.32 -3,101.36 MWD+IFR-AK-CAZ-SC(3) 8,473.31 56.71 309.14 5,583.17 5,424.07 -1,398.62 -5,148.83 5,928,563.25 475,746.25 0.83 -3,075.28 MWD+IFR-AK-CAZ-SC(3) 8,564.64 55.84 310.08 5,633.88 5,474.78 -1,350.20 -5,207.35 5,928,611.82 475,687.86 1.28 -3,049.79 MWD+IFR-AK-CAZ-SC(3) 8,659.27 55.94 311.96 5,686.95 5,527.85 -1,298.78 -5,266.46 5,928,663.38 475,628.88 1.65 -3,021.69 MWD+IFR-AK-CAZ-SC(3) 8,752.97 57.18 315.11 5,738.59 5,579.49 -1,244.92 -5,323.12 5,928,717.38 475,572.37 3.10 -2,990.46 MWD+IFR-AK-CAZ-SC(3) 8,847.00 58.26 317.39 5,788.82 5,629.72 -1,187.50 -5,378.08 5,928,774.93 475,517.56 2.35 -2.955.29 NOT an Actual Survey 10-3/4"x 13-1/2"-Top of 10-3/4"casing window 8,867.00 60.11 316.14 5,799.06 5,639.96 -1,174.99 -5,389.85 5,928,787.47 475,505.82 10.69 -2,947.56 INC+TREND(4) 8,938.22 60.40 318.61 5,834.40 5,675.30 -1,129.49 -5,431.72 5,928,833.07 475,464.07 3.04 -2,919.13 INC+TREND(4) 9,033.16 61.50 321.89 5,880.51 5,721.41 -1,065.69 -5,484.77 5,928,897.00 475,411.19 3.23 -2,877.32 INC+TREND(4) 9,128.47 63.09 325.16 5,924.83 5,765.73 -997.84 -5,534.90 5,928,964.97 475,361.23 3.47 -2,830.71 INC+TREND(4) 9,224.66 63.51 328.41 5,968.06 5,808.96 -925.95 -5,581.96 5,929,036.97 475,314.36 3.05 -2,779.26 INC+TREND(4) 9,318.30 62.62 331.53 6,010.48 5,851.38 -853.70 -5,623.74 5,929,109.32 475,272.77 3.12 -2,725.65 MWD+IFR-AK-CAZ-SC(5) 9,375.23 63.12 332.63 6,036.44 5,877.34 -808.93 -5,647.46 5,929,154.15 475,249.16 1.93 -2,691.69 MWD+IFR-AK-CAZ-SC(5) 9,412.83 63.99 333.29 6,053.19 5,894.09 -778.94 -5,662.77 5,929,184.17 475,233.93 2.80 -2,668.75 MWD+IFR-AK-CAZ-SC(5) 9,461.94 65.63 334.82 6,074.09 5,914.99 -738.98 -5,682.21 5,929,224.17 475,214.60 4.37 -2,637.85 MWD+IFR-AK-CAZ-SC(5) 9,507.98 65.70 334.76 6,093.06 5,933.96 -701.03 -5,700.07 5,929,262.17 475,196.83 0.19 -2,608.29 MWD+IFR-AK-CAZ-SC(5) 9,602.61 66.32 333.71 6,131.54 5,972.44 -623.17 -5,737.66 5,929,340.11 475,159.45 1.21 -2,547.98 MWD+IFR-AK-CAZ-SC(5) 9,647.82 66.88 333.74 6,149.49 5,990.39 -585.97 -5,756.02 5,929,377.36 475,141.18 1.24 -2,519.30 MWD+IFR-AK-CAZ-SC(5) 9,696.77 67.55 333.33 6,168.45 6,009.35 -545.57 -5,776.14 5,929,417.81 475,121.17 1.57 -2,488.22 MWD+IFR-AK-CAZ-SC(5) 9,791.94 67.87 336.22 6,204.55 6,045.45 -465.92 -5,813.66 5,929,497.55 475,083.85 2.83 -2,426.20 MWD+IFR-AK-CAZ-SC(5) 9,886.71 68.93 339.38 6,239.45 6,080.35 -384.34 -5,846.94 5,929,579.19 475,050.78 3.30 -2,360.93 MWD+IFR-AK-CAZ-SC(5) 9,981.86 71.62 341.84 6,271.56 6,112.46 -299.87 -5,876.65 5,929,663.74 475,021.28 3.73 -2,291.72 MWD+IFR-AK-CAZ-SC(5) 10,076.71 74.36 344.43 6,299.31 6,140.21 -213.08 -5,902.95 5,929,750.58 474,995.21 3.89 -2,219.16 MWD+IFR-AK-CAZ-SC(5) 10,171.00 78.01 345.70 6,321.83 6,162.73 -124.63 -5,926.53 5,929,839.09 474,971.85 4.09 -2,144.10 MWD+IFR-AK-CAZ-SC(5) 10,265.91 81.96 347.61 6,338.33 6,179.23 -33.71 -5,948.09 5,929,930.05 474,950.53 4.61 -2,066.04 MWD+IFR-AK-CAZ-SC(5) 10,350.09 85.54 348.73 6,347.49 6,188.39 48.18 -5,965.24 5,930,011.97 474,933.59 4.45 -1,994.95 MWD+IFR-AK-CAZ-SC(5) 10,410.00 87.66 350.32 6,351.05 6,191.95 106.99 -5,976.11 5,930,070.80 474,922.87 4.42 -1,943.41 NOT an Actual Survey 7-6/8"x 9-7/8" 10,439.96 88.72 351.12 6,351.99 6,192.89 136.54 -5,980.93 5,930,100.36 474,918.12 4.42 -1,917.30 MWD+IFR-AK-CAZ-SC(6) 10,535.42 91.10 353.56 6,352.14 6,193.04 231.13 -5,993.66 5,930,194.98 474,905.63 3.57 -1,832.76 MWD+IFR-AK-CAZ-SC(6) 10,629.83 92.61 355.61 6,349.09 6,189.99 325.06 -6,002.56 5,930,288.92 474,896.97 2.70 -1,747.54 MWD+IFR-AK-CAZ-SC(6) 10,724.25 92.92 0.19 6,344.53 6,185.43 419.29 -6,006.02 5,930,383.14 474,893.75 4.86 -1,660.18 MWD+IFR-AK-CAZ-SC(6) 10,819.52 93.12 3.70 6,339.51 6,180.41 514.35 -6,002.79 5,930,478.19 474,897.22 3.69 -1,569.74 MWD+IFR-AK-CAZ-SC(6) 10,913.73 92.54 6.90 6,334.86 6,175.76 608.03 -5,994.10 5,930,571.84 474,906.15 3.45 -1,478.74 MWD+IFR-AK-CAZ-SC(6) 12/14/2016 8:57:15AM Page 5 COMPASS 50004 Build 74 • ! Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,008.58 91.57 11.24 6,331.45 6,172.35 701.61 -5,979.16 5930,665.37 474,921.32 4.69 -1,385.69 MWD+IFR-AK-CAZ-SC(6) 11,103.97 91.78 14.68 6,328.66 6,169.56 794.52 -5,957.78 5,930,758.22 474,942.94 3.61 -1,291.07 MWD+IFR-AK-CAZ-SC(6) 11,198.72 91.89 18.27 6,325.63 6,166.53 885.32 -5,930.92 5,930,848.94 474,970.02 3.79 -1,196.57 MWD+IFR-AK-CAZ-SC(6) 11,293.57 92.68 19.08 6,321.85 6,162.75 975.10 -5,900.58 5,930,938.63 475,000.59 1.19 -1,101.82 MWD+IFR-AK-CAZ-SC(6) 11,388.82 92.12 18.72 6,317.86 6,158.76 1,065.14 -5,869.75 5,931,028.58 475,031.64 0.70 -1,006.67 MWD+IFR-AK-CAZ-SC(6) 11,483.52 92.63 18.77 6,313.93 6,154.83 1,154.74 -5,839.35 5,931,118.10 475,062.27 0.54 -912.08 MWD+IFR-AK-CAZ-SC(6) 11,577.75 90.23 19.57 6,311.58 6,152.48 1,243.71 -5,808.42 5,931,206.98 475,093.42 2.68 -817.89 MWD+IFR-AK-CAZ-SC(6) 11,673.11 89.06 19.46 6,312.17 6,153.07 1,333.59 -5,776.56 5,931,296.77 475,125.50 1.23 -722.54 MWD+IFR-AK-CAZ-SC(6) 11,767.34 89.06 18.28 6,313.72 6,154.62 1,422.74 -5,746.09 5,931,385.83 475,156.19 1.25 -628.34 MWD+IFR-AK-CAZ-SC(6) 11,862.17 90.17 17.52 6,314.36 6,155.26 1,512.97 -5,716.94 5,931,475.99 475,185.56 1.42 -533.58 MWD+IFR-AK-CAZ-SC(6) 11,957.60 90.48 16.29 6,313.81 6,154.71 1,604.28 -5,689.20 5,931,567.21 475,213.54 1.33 -438.29 MWD+IFR-AK-CAZ-SC(6) 12,051.62 90.34 14.65 6,313.14 6,154.04 1,694.88 -5,664.12 5,931,657.74 475,238.84 1.75 -344.57 MWD+IFR-AK-CAZ-SC(6) 12,146.27 90.65 13.51 6,312.32 6,153.22 1,786.69 -5,641.09 5,931,749.48 475,262.10 1.25 -250.43 MWD+IFR-AK-CAZ-SC(6) 12,240.60 90.72 12.99 6,311.20 6,152.10 1,878.50 -5,619.48 5,931,841.23 475,283.95 0.56 -156.76 MWD+IFR-AK-CAZ-SC(6) 12,334.63 91.10 12.43 6,309.70 6,150.60 1,970.21 -5,598.79 5,931,932.88 475,304.86 0.72 -63.51 MWD+IFR-AK-CAZ-SC(6) 12,429.40 91.23 14.01 6,307.78 6,148.68 2,062.45 -5,577.12 5,932,025.05 475,326.76 1.67 30.58 MWD+IFR-AK-CAZ-SC(6) 12,523.32 90.61 14.69 6,306.27 6,147.17 2,153.42 -5,553.85 5,932,115.96 475,350.26 0.98 124.03 MWD+IFR-AK-CAZ-SC(6) 12,617.71 90.99 15.51 6,304.95 6,145.85 2,244.55 -5,529.26 5,932,207.01 475,375.08 0.96 218.06 MWD+IFR-AK-CAZ-SC(6) 12,713.41 90.75 15.71 6,303.50 6,144.40 2,336.71 -5,503.51 5,932,299.09 475,401.06 0.33 313.47 MWD+IFR-AK-CAZ-SC(6) 12,807.98 91.27 16.49 6,301.83 6,142.73 2,427.55 -5,477.29 5,932,389.86 475,427.51 0.99 407.81 MWD+IFR-AK-CAZ-SC(6) 12,903.10 91.30 16.20 6,299.70 6,140.60 2,518.80 -5,450.53 5,932,481.04 475,454.50 0.31 502.71 MWD+IFR-AK-CAZ-SC(6) 12,997.68 91.71 16.65 6,297.21 6,138.11 2,609.49 -5,423.80 5,932,571.65 475,481.46 0.64 597.07 MWD+IFR-AK-CAZ-SC(6) 13,092.51 91.85 16.59 6,294.27 6,135.17 2,700.32 -5,396.68 5,932,662.40 475,508.79 0.16 691.69 MWD+IFR-AK-CAZ-SC(6) 13,187.36 91.09 14.95 6,291.83 6,132.73 2,791.56 -5,370.92 5,932,753.57 475,534.79 1.91 786.25 MWD+IFR-AK-CAZ-SC(6) 13,282.41 91.54 14.65 6,289.65 6,130.55 2,883.43 -5,346.64 5,932,845.37 475,559.29 0.57 880.88 MWD+IFR-AK-CAZ-SC(6) 13,376.96 91.68 13.95 6,287.00 6,127.90 2,975.02 -5,323.30 5,932,936.88 475,582.87 0.75 974.93 MWD+IFR-AK-CAZ-SC(6) 13,472.42 91.65 13.72 6,284.22 6,125.12 3,067.67 -5,300.48 5,933,029.47 475,605.92 0.24 1,069.80 MWD+IFR-AK-CAZ-SC(6) 13,567.08 91.85 12.99 6,281.33 6,122.23 3,159.73 -5,278.63 5,933,121.46 475,628.00 0.80 1,163.77 MWD+IFR-AK-CAZ-SC(6) 13,661.67 91.92 13.17 6,278.22 6,119.12 3,251.81 -5,257.23 5,933,213.48 475,649.63 0.20 1,257.62 MWD+IFR-AK-CAZ-SC(6) 13,756.58 91.72 14.02 6,275.21 6,116.11 3,344.02 -5,234.93 5,933,305.62 475,672.16 0.92 1,351.89 MWD+IFR-AK-CAZ-SC(6) 13,851.57 91.04 14.42 6,272.92 6,113.82 3,436.07 -5,211.61 5,933,397.60 475,695.71 0.83 1,446.37 MWD+IFR-AK-CAZ-SC(6) 13,945.61 88.46 14.61 6,273.33 6,114.23 3,527.10 -5,188.04 5,933,488.56 475,719.51 2.75 1,539.97 MWD+IFR-AK-CAZ-SC(6) 14,039.92 86.30 13.63 6,277.64 6,118.54 3,618.46 -5,165.06 5,933,579.85 475,742.72 2.51 1,633.68 MWD+IFR-AK-CAZ-SC(6) 14,134.35 87.29 13.68 6,282.92 6,123.82 3,710.07 -5,142.80 5,933,671.41 475,765.21 1.05 1,727.39 MWD+IFR-AK-CAZ-SC(6) 14,229.07 87.22 13.73 6,287.46 6,128.36 3,801.99 -5,120.38 5,933,763.26 475,787.85 0.09 1,821.43 MWD+IFR-AK-CAZ-SC(6) 14,323.19 87.19 13.00 6,292.04 6,132.94 3,893.45 -5,098.65 5,933,854.65 475,809.81 0.78 1,914.80 MWD+IFR-AK-CAZ-SC(6) 14,417.40 88.04 13.48 6,295.97 6,136.87 3,985.08 -5,077.10 5,933,946.22 475,831.60 1.04 2,008.28 MWD+IFR-AK-CAZ-SC(6) 14,512.01 88.42 14.13 6,298.89 6,139.79 4,076.91 -5,054.53 5,934,037.98 475,854.40 0.80 2,102.29 MWD+IFR-AK-CAZ-SC(6) 14,606.89 87.98 15.06 6,301.87 6,142.77 4,168.68 -5,030.63 5,934,129.68 475,878.52 1.08 2,196.70 MWD+IFR-AK-CAZ-SC(6) 14,701.10 88.06 15.99 6,305.12 6,146.02 4,259.40 -5,005.43 5,934,220.33 475,903.95 0.99 2,290.57 MWD+IFR-AK-CAZ-SC(6) 12/14/2016 8:57:15AM Page 6 COMPASS 5000.1 Build 74 • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,796.86 90.15 16.94 6,306.62 6,147.52 4,351.21 -4,978.30 5,934,312.06 475,931.32 2.40 2,386.13 MWD+IFR-AK-CAZ-SC(6) 14,890.11 89.90 18.40 6,306.58 6,147.48 4,440.06 -4,949.99 5,934,400.83 475,959.84 1.59 2,479.30 MWD+IFR-AK-CAZ-SC(6) 14,985.25 90.40 17.40 6,306.33 6,147.23 4,530.59 -4,920.75 5,934,491.28 475,989.31 1.18 2,574.37 MWD+IFR-AK-CAZ-SC(6) 15,081.04 92.14 18.38 6,304.21 6,145.11 4,621.73 -4,891.34 5,934,582.33 476,018.95 2.08 2,670.07 MWD+IFR-AK-CAZ-SC(6) 15,176.99 91.99 19.58 6,300.75 6,141.65 4,712.40 -4,860.15 5,934,672.91 476,050.37 1.26 2,765.94 MWD+IFR-AK-CAZ-SC(6) 15,266.87 92.23 20.48 6,297.44 6,138.34 4,796.78 -4,829.39 5,934,757.21 476,081.34 1.04 2,855.76 MWD+IFR-AK-CAZ-SC(6) 15,360.63 91.75 19.36 6,294.18 6,135.08 4,884.88 -4,797.46 5,934,845.22 476,113.48 1.30 2,949.46 MWD+IFR-AK-CAZ-SC(6) 15,452.95 91.92 17.63 6,291.23 6,132.13 4,972.38 -4,768.19 5,934,932.64 476,142.97 1.88 3,041.69 MWD+IFR-AK-CAZ-SC(6) 15,545.52 91.58 15.86 6,288.40 6,129.30 5,060.98 -4,741.53 5,935,021.16 476,169.85 1.95 3,134.07 MWD+IFR-AK-CAZ-SC(6) 15,638.03 •91.37 14.43 6,286.02 6,126.92 5,150.25 -4,717.37 5,935,110.36 476,194.23 1.56 3,226.21 MWD+IFR-AK-CAZ-SC(6) 15,731.19 91.68 13.56 6,283.54 6,124.44 5,240.61 -4,694.85 5,935,200.65 476,216.98 0.99 3,318.83 MWD+IFR-AK-CAZ-SC(6) 15,823.03 92.33 12.64 6,280.33 6,121.23 5,330.00 -4,674.05 5,935,289.98 476,238.01 1.23 3,409.95 MWD+IFR-AK-CAZ-SC(6) 15,914.11 91.82 12.39 6,277.03 6,117.93 5,418.86 -4,654.33 5,935,378.78 476,257.96 0.62 3,500.19 MWD+IFR-AK-CAZ-SC(6) 16,007.20 92.07 13.43 6,273.87 6,114.77 5,509.54 -4,633.54 5,935,469.40 476,278.97 1.15 3,592.51 MWD+IFR-AK-CAZ-SC(6) 16,097.95 90.35 14.16 6,271.95 6,112.85 5,597.65 -4,611.91 5,935,557.45 476,300.82 2.06 3,682.71 MWD+IFR-AK-CAZ-SC(6) 16,189.55 91.47 15.39 6,270.50 6,111.40 5,686.21 -4,588.55 5,935,645.94 476,324.40 1.82 3,773.91 MWD+IFR-AK-CAZ-SC(6) 16,281.22 91.82 18.29 6,267.86 6,108.76 5,773.90 -4,562.01 5,935,733.55 476,351.16 3.19 3,865.40 MWD+IFR-AK-CAZ-SC(6) 16,372.57 91.61 20.89 6,265.13 6,106.03 5,859.92 -4,531.40 5,935,819.48 476,381.99 2.85 3,956.69 MWD+IFR-AK-CAZ-SC(6) 16,465.96 91.75 21.04 6,262.39 6,103.29 5,947.09 -4,498.00 5,935,906.56 476,415.61 0.22 4,050.03 MWD+IFR-AK-CAZ-SC(6) 16,557.37 91.99 21.05 6,259.41 6,100.31 6,032.36 -4,465.19 5,935,991.74 476,448.63 0.26 4,141.38 MWD+IFR-AK-CAZ-SC(6) 16,649.73 91.96 20.73 6,256.23 6,097.13 6,118.59 -4,432.27 5,936,077.88 476,481.76 0.35 4,233.67 MWD+IFR-AK-CAZ-SC(6) 16,742.46 91.34 20.53 6,253.56 6,094.46 6,205.34 -4,399.62 5,936,164.54 476,514.63 0.70 4,326.36 MWD+IFR-AK-CAZ-SC(6) 16,833.45 91.20 21.13 6,251.54 6,092.44 6,290.36 -4,367.27 5,936,249.47 476,547.19 0.68 4,417.31 MWD+IFR-AK-CAZ-SC(6) 16,856.69 91.34 21.19 6,251.02 6,091.92 6,312.03 -4,358.88 5,936,271.11 476,555.63 0.66 4,440.54 MWD+IFR-AK-CAZ-SC(6) 16,907.00 91.34 21.19 6,249.85 6,090.75 6,358.93 -4,340.70 5,936,317.96 476,573.93 0.00 4,490.83 NOT an Actual Survey 41/2"x 6-3/4" 16,917.00 91.34 21.19 6,249.61 6,090.51 6,368.25 -4,337.09 5,936,327.27 476,577.56 0.00 4,500.82 PROJECTED to TD 12/14/2016 8:57'15AM Page 7 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-off Ail targets and/or well position objectives have been achieved. L Yes L No I have checked to the best of my ability that the following data is correct: • Surface Coordinates O Declination & Convergence GRS Survey Corrections • Survey Tool Codes Dynan,.limed doma ON c,-V cervi Chars, Vincent Osarar-mi�K, 115 SLB DE: Ortr.71>,i,,.,4 D9,141:6.09{0 pgifal Xr li .^:'W' yri Client Representative: SCOtt BrUnSWICk Date: 14-Dec-2016 • •• 21 81 04 27877 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-13A F ECE1V5 JAN 132017 ACGCC Definitive Survey Report 13 December, 2016 NAD 83 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-13 Well Position +N/-S 0.00 usft Northing: 5,929,698.28 usft Latitude: 70°13'10.067 N +E/-W 0.00 usft Easting: 1,620,931.42 usft Longitude: 150°9'25.916 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore 2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BG G M2016 12/1/2016 17.71 80.84 57,531 Design 2S-13A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,752.87 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 20.00 Survey Program Date 12/13/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 94.28 1,295.18 2S-13PB1 Srvy#1-SLB_NSG+Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2: 1,316.39 2,787.14 2S-13PB1 Srvy#2-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:21 2,879.81 8,752.87 2S-13PB1 Srvy#3-SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 8,847.00 9,224.66 2S-13A Srvy 1-SLB_INC+Filler(2S-13A INC+TREND Inclinometer+known azi trend 11/10/2016 11:11 9,318.30 10,350.09 2S-13A Srvy 2-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2016 11:2' 10,350.09 16,856.69 2S-13A Srvy 3-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/18/2016 9:48 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,698.28 1,620,931.42 0.00 0.00 UNDEFINED 94.28 0.03 287.05 94.28 -64.82 0.00 -0.01 5,929,698.29 1,620,931 40 0.05 0.00 GYD-G0-SS 11) 119.10 0.04 238.86 119.10 -40.00 0.00 -0.03 5,929,698.29 1,620,931.39 0.11 -0.01 I NOT an Actual Survey 20"x 42" 186.46 0.10 201.50 186.46 27.36 -0.06 -0.07 5,929,698.22 1,620,931.35 0.11 -0.08 GYD-GC-SS(1) 278.50 0.54 204.98 278.50 119.40 -0.53 -0.28 5,929,697.75 1,620,931.14 0.48 -0.59 GYD-GC-SS(1) 370.52 2.63 196.47 370.48 211.38 -2.95 -1.06 5,929,695.34 1,620,930.35 2.28 -3.13 GYD-GC-SS(1) 462.15 4.08 197.58 461.95 302.85 -8.07 -2.64 5,929,690.22 1,620,928.75 1.58 -8.49 GYD-GC-SS(1) 554.04 4.84 198.23 553.56 394.46 -14.87 -4.84 5,929,683.43 1,620,926.54 0.83 -15.63 GYD-GC-SS(1) 645.95 5.99 202.27 645.06 485.96 -22.99 -7.87 5,929,675.31 1,620,923.48 1.32 -24.30 GYD-GC-SS(1) 12/13/2016 12:30:16PM Page 2 COMPASS 5000.1 Build 74 • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 737.60 6.53 203.78 736.16 577.06 -32.19 -11.79 5,929,666.13 1,620,919.55 0.62 -34.28 GYD-GC-SS(1) 829.54 8.48 201.86 827.31 668.21 -43.26 -16.42 5,929,655.07 1,620,914.89 2.14 -46.27 GYD-GC-SS(1) 922.16 9.80 205.54 918.75 759.65 -56.71 -22.36 5,929,641.63 1,620,908.91 1.56 -60.94 GYD-GC-SS(1) 1,015.46 11.08 208.23 1,010.51 851.41 -71.78 -30.02 5,929,626.59 1,620,901.21 1.47 -77.72 GYD-GC-SS(1) 1,107.69 12.93 209.29 1,100.72 941.62 -88.59 -39.27 5,929,609.81 1,620,891.93 2.02 -96.67 GYD-GC-SS(1) 1,200.16 15.38 208.11 1,190.37 1,031.27 -108.43 -50.11 5,929,589.99 1,620,881.03 2.67 -119.03 GYD-GC-SS(1) 1,295.18 19.22 206.89 1,281.08 1,121.98 -133.50 -63.12 5,929,564.96 1,620,867.96 4.06 -147.04 GYD-GC-SS(1) 1,316.39 20.60 207.96 1,301.02 1,141.92 -139.91 -66.45 5,929,558.56 1,620,864.61 6.73 -154.20 MWD+IFR-AK-CAZ-SC(2) 1,408.27 21.80 208.96 1,386.68 1,227.58 -169.12 -82.29 5,929,529.40 1,620,848.70 1.36 -187.06 MWD+IFR-AK-CAZ-SC(2) 1,502.81 25.56 213.09 1,473.25 1,314.15 -201.58 -101.93 5,929,496.99 1,620,828.97 4.34 -224.28 MWD+IFR-AK-CAZ-SC(2) 1,596.76 27.45 217.68 1,557.33 1,398.23 -235.70 -126.24 5,929,462.93 1,620,804.58 2.97 -264.66 MWD+IFR-AK-CAZ-SC(2) 1,689.53 29.30 221.23 1,638.96 1,479.86 -269.70 -154.27 5,929,429.01 1,620,776.46 2.70 -306.20 MWD+IFR-AK-CAZ-SC(2) 1,783.35 30.21 225.91 1,720.42 1,561.32 -303.40 -186.36 5,929,395.40 1,620,744.29 2.66 -348.84 MWD+IFR-AK-CAZ-SC(2) 1,875.34 31.06 226.45 1,799.57 1,640.47 -335.85 -220.19 5,929,363.04 1,620,710.39 0.97 -390.90 MWD+IFR-AK-CAZ-SC(2) 1,968.32 32.83 229.72 1,878.47 1,719.37 -368.68 -256.80 5,929,330.31 1,620,673.69 2.66 -434.28 MWD+IFR-AK-CAZ-SC(2) 2,061.97 33.68 233.62 1,956.79 1,797.69 -400.50 -297.08 5,929,298.60 1,620,633.33 2.46 -477.95 MWD+IFR-AK-CAZ-SC(2) 2,154.77 34.26 235.37 2,033.75 1,874.65 -430.60 -339.29 5,929,268.60 1,620,591.05 1.23 -520.68 MWD+IFR-AK-CAZ-SC(2) 2,249.17 35.48 238.69 2,111.21 1,952.11 -459.94 -384.57 5,929,239.38 1,620,545.70 2.39 -563.74 MWD+IFR-AK-CAZ-SC(2) 2,342.07 38.90 240.04 2,185.21 2,026.11 -488.53 -432.89 5,929,210.92 1,620,497.31 3.78 -607.12 MWD+IFR-AK-CAZ-SC(2) 2,435.49 39.45 242.06 2,257.63 2,098.53 -517.09 -484.53 5,929,182.50 1,620,445.61 1.49 -651.62 MWD+IFR-AK-CAZ-SC(2) 2,526.64 40.79 245.52 2,327.34 2,168.24 -543.00 -537.21 5,929,156.73 1,620,392.85 2.85 -693.99 MWD+IFR-AK-CAZ-SC(2) 2,620.76 42.70 247.70 2,397.57 2,238.47 -567.85 -594.73 5,929,132.03 1,620,335.28 2.55 -737.01 MWD+IFR-AK-CAZ-SC(2) 2,713.46 43.56 247.40 2,465.22 2,306.12 -592.05 -653.30 5,929,107.98 1,620,276.65 0.95 -779.79 MWD+IFR-AK-CAZ-SC(2) 2,787.14 45.32 247.46 2,517.82 2,358.72 -611.85 -700.94 5,929,088.31 1,620,228.97 2.39 -814.69 MWD+IFR-AK-CAZ-SC(2) I2,846.60 46.00 247.45 2,559.38 2,400.28 -628.16 -740.21 5,929,072.10 1,620,189.66 1.14 -843.44 A NOT anAcWdSurvey) 13-3/8"x 16" 2,879.61 46.37 247.44 2,582.24 2,423.14 -637.29 -762.21 5,929,063.03 1,620,167.64 1.14 -859.55 MWD+IFR-AK-CAZ-SC(3) 2,973.48 45.93 246.36 2,647.27 2,488.17 -663.85 -824.47 5,929,036.63 1,620,105.31 0.95 -905.80 MWD+IFR-AK-CAZ-SC(3) 3,064.84 45.12 245.87 2,711.27 2,552.17 -690.24 -884.08 5,929,010.40 1,620,045.64 0.97 -950.99 MWD+IFR-AK-CAZ-SC(3) 3,156.72 45.68 246.79 2,775.79 2,616.69 -716.50 -944.00 5,928,984.29 1,619,985.67 0.94 -996.16 MWD+IFR-AK-CAZ-SC(3) 3,249.58 47.31 247.54 2,839.71 2,680.61 -742.63 -1,006.07 5,928,958.32 1,619,923.53 1.85 -1,041.94 MWD+IFR-AK-CAZ-SC(3) 3,344.32 50.46 248.03 2,902.00 2,742.90 -769.61 -1,072.14 5,928,931.52 1,619,857.40 3.35 -1,089.89 MWD+IFR-AK-CAZ-SC(3) 3,437.25 51.28 247.93 2,960.65 2,801.55 -796.64 -1,138.97 5,928,904.67 1,619,790.51 0.89 -1,138.15 MWD+IFR-AK-CAZ-SC(3) 3,530.59 55.39 247.67 3,016.37 2,857.27 -824.93 -1,208.28 5,928,876.56 1,619,721.13 4.41 -1,188.43 MWD+IFR-AK-CAZ-SC(3) 3,621.02 56.46 248.04 3,067.04 2,907.94 -853.16 -1,277.65 5,928,848.51 1,619,651.69 1.23 -1,238.69 MWD+IFR-AK-CAZ-SC(3) 3,714.87 57.86 248.01 3,117.93 2,958.83 -882.67 -1,350.77 5,928,819.20 1,619,578.50 1.49 -1,291.43 MWD+IFR-AK-CAZ-SC(3) 3,806.95 58.60 248.24 3,166.41 3,007.31 -911.83 -1,423.42 5,928,790.22 1,619,505.79 0.83 -1,343.68 MWD+IFR-AK-CAZ-SC(3) 3,900.29 62.00 248.65 3,212.65 3,053.55 -941.61 -1,498.82 5,928,760.64 1,619,430.32 3.66 -1,397.45 MWD+IFR-AK-CAZ-SC(3) 3,994.62 62.42 248.93 3,256.63 3,097.53 -971.80 -1,576.62 5,928,730.65 1,619,352.45 0.52 -1,452.43 MWD+IFR-AK-CAZ-SC(3) 4,086.87 61.97 248.44 3,299.66 3,140.56 -1,001.46 -1,652.63 5,928,701.19 1,619,276.37 0.68 -1,506.30 MWD+IFR-AK-CAZ-SC(3) 12/13/2016 12:30:16PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,179.93 61.01 250.91 3,344.09 3,184.99 -1,029.87 -1,729.30 5,928,672.99 1,619,199.63 2.55 -1,559.22 MWD+IFR-AK-CAZ-SC(3) 4,273.79 60.59 251.46 3,389.88 3,230.78 -1,056.29 -1,806.86 5,928,646.76 1,619,122.02 0.68 -1,610.57 MWD+IFR-AK-CAZ-SC(3) 4,368.17 60.80 251.48 3,436.07 3,276.97 -1,082.45 -1,884.89 5,928,620.81 1,619,043.92 0.22 -1,661.84 MWD+IFR-AK-CAZ-SC(3) 4,461.58 61.03 251.32 3,481.48 3,322.38 -1,108.49 -1,962.26 5,928,594.98 1,618,966.50 0.29 -1,712.77 MWD+IFR-AK-CAZ-SC(3) 4,556.36 61.00 251.15 3,527.41 3,368.31 -1,135.16 -2,040.76 5,928,568.51 1,618,887.93 0.16 -1,764.68 MWD+IFR-AK-CAZ-SC(3) 4,650.19 61.06 250.63 3,572.86 3,413.76 -1,162.03 -2,118.33 5,928,541.84 1,618,810.31 0.49 -1,816.46 MWD+IFR-AK-CAZ-SC(3) 4,743.61 60.86 249.57 3,618.21 3,459.11 -1,189.83 -2,195.12 5,928,514.24 1,618,733.45 1.01 -1,868.85 MWD+IFR-AK-CAZ-SC(3) 4,837.87 60.79 250.20 3,664.16 3,505.06 -1,218.13 -2,272.40 5,928,486.14 1,618,656.10 0.59 -1,921.88 MWD+IFR-AK-CAZ-SC(3) 4,928.53 61.06 250.33 3,708.21 3,549.11 -1,244.89 -2,346.99 5,928,459.58 1,618,581.46 0.32 -1,972.53 MWD+IFR-AK-CAZ-SC(3) 5,021.88 61.10 250.12 3,753.36 3,594.26 -1,272.53 -2,423.88 5,928,432.14 1,618,504.50 0.20 -2,024.81 MWD+IFR-AK-CAZ-SC(3) 5,114.38 60.72 250.05 3,798.33 3,639.23 -1,300.07 -2,499.87 5,928,404.80 1,618,428.44 0.42 -2,076.67 MWD+IFR-AK-CAZ-SC(3) 5,206.88 60.66 249.61 3,843.61 3,684.51 -1,327.88 -2,575.59 5,928,377.19 1,618,352.67 0.42 -2,128.70 MWD+IFR-AK-CAZ-SC(3) 5,300.97 60.74 250.17 3,889.66 3,730.56 -1,356.09 -2,652.64 5,928,349.18 1,618,275.55 0.53 -2,181.56 MWD+IFR-AK-CAZ-SC(3) 5,393.35 60.67 250.09 3,934.86 3,775.76 -1,383.47 -2,728.41 5,928,322.00 1,618,199.72 0.11 -2,233.21 MWD+IFR-AK-CAZ-SC(3) 5,485.05 60.63 250.62 3,979.80 3,820.70 -1,410.35 -2,803.68 5,928,295.32 1,618,124.38 0.51 -2,284.21 MWD+IFR-AK-CAZ-SC(3) 5,579.52 60.66 250.87 4,026.11 3,867.01 -1,437.50 -2,881.42 5,928,268.37 1,618,046.59 0.23 -2,336.31 MWD+IFR-AK-CAZ-SC(3) 5,673.28 60.74 251.47 4,072.00 3,912.90 -1,463.89 -2,958.80 5,928,242.18 1,617,969.14 0.56 -2,387.58 MWD+IFR-AK-CAZ-SC(3) 5,768.68 60.53 251.29 4,118.78 3,959.68 -1,490.44 -3,037.60 5,928,215.84 1,617,890.29 0.27 -2,439.47 MWD+IFR-AK-CAZ-SC(3) 5,862.17 60.90 250.91 4,164.51 4,005.41 -1,516.85 -3,114.74 5,928,189.63 1,617,813.08 0.53 -2,490.68 MWD+IFR-AK-CAZ-SC(3) 5,955.59 60.44 248.47 4,210.28 4,051.18 -1,545.11 -3,191.11 5,928,161.57 1,617,736.64 2.33 -2,543.35 MWD+IFR-AK-CAZ-SC(3) 6,048.82 60.79 249.67 4,256.03 4,096.93 -1,574.13 -3,266.99 5,928,132.75 1,617,660.70 1.18 -2,596.57 MWD+IFR-AK-CAZ-SC(3) 6,141.13 60.59 248.07 4,301.22 4,142.12 -1,603.14 -3,342.06 5,928,103.93 1,617,585.56 1.53 -2,649.51 MWD+IFR-AK-CAZ-SC(3) 6,234.01 60.88 248.38 4,346.62 4,187.52 -1,633.20 -3,417.31 5,928,074.07 1,617,510.24 0.43 -2,703.49 MWD+IFR-AK-CAZ-SC(3) 6,327.61 60.70 248.15 4,392.30 4,233.20 -1,663.45 -3,493.20 5,928,044.02 1,617,434.28 0.29 -2,757.88 MWD+IFR-AK-CAZ-SC(3) 6,420.92 60.61 250.20 4,438.03 4,278.93 -1,692.37 -3,569.22 5,928,015.30 1,617,358.20 1.92 -2,811.05 MWD+IFR-AK-CAZ-SC(3) 6,513.98 58.16 250.88 4,485.42 4,326.32 -1,719.05 -3,644.72 5,927,988.82 1,617,282.63 2.71 -2,861.95 MWD+IFR-AK-CAZ-SC(3) 6,609.81 58.41 253.51 4,535.80 4,376.70 -1,743.97 -3,722.33 5,927,964.10 1,617,204.97 2.35 -2,911.91 MWD+IFR-AK-CAZ-SC(3) 6,700.72 58.87 256.33 4,583.12 4,424.02 -1,764.16 -3,797.27 5,927,944.11 1,617,129.98 2.70 -2,956.51 MWD+IFR-AK-CAZ-SC(3) 6,795.26 59.28 258.89 4,631.71 4,472.61 -1,781.56 -3,876.47 5,927,926.92 1,617,050.74 2.36 -2,999.95 MWD+IFR-AK-CAZ-SC(3) 6,890.38 58.49 262.31 4,680.88 4,521.78 -1,794.87 -3,956.79 5,927,913.82 1,616,970.39 3.19 -3,039.92 MWD+IFR-AK-CAZ-SC(3) 6,986.56 57.42 266.31 4,731.92 4,572.82 -1,802.96 -4,037.89 5,927,905.93 1,616,889.29 3.70 -3,075.27 MWD+IFR-AK-CAZ-SC(3) 7,079.86 56.96 269.00 4,782.48 4,623.38 -1,806.17 -4,116.23 5,927,902.92 1,616,810.95 2.47 -3,105.08 MWD+IFR-AK-CAZ-SC(3) 7,173.85 56.44 272.56 4,834.10 4,675.00 -1,805.11 -4,194.76 5,927,904.19 1,616,732.43 3.21 -3,130.94 MWD+IFR-AK-CAZ-SC(3) 7,265.88 55.85 275.87 4,885.38 4,726.28 -1,799.50 -4,270.96 5,927,909.99 1,616,656.25 3.05 -3,151.74 MWD+IFR-AK-CAZ-SC(3) 7,357.32 55.88 278.70 4,936.70 4,777.60 -1,789.91 -4,346.02 5,927,919.78 1,616,581.22 2.56 -3,168.39 MWD+IFR-AK-CAZ-SC(3) 7,452.65 55.03 280.27 4,990.75 4,831.65 -1,776.97 -4,423.47 5,927,932.91 1,616,503.82 1.62 -3,182.73 MWD+IFR-AK-CAZ-SC(3) 7,544.85 52.88 282.42 5,045.01 4,885.91 -1,762.33 -4,496.55 5,927,947.74 1,616,430.78 3.00 -3,193.96 MWD+IFR-AK-CAZ-SC(3) 7,637.54 51.57 285.38 5,101.79 4,942.69 -1,744.75 -4,567.66 5,927,965.50 1,616,359.72 2.89 -3,201.76 MWD+IFR-AK-CAZ-SC(3) 7,731.01 52.60 289.78 5,159.25 5,000.15 -1,722.47 -4,637.92 5,927,987.96 1,616,289.53 3.87 -3,204.85 MWD+IFR-AK-CAZ-SC(3) 7,823.31 53.12 292.34 5,214.98 5,055.88 -1,696.03 -4,706.57 5,928,014.58 1,616,220.95 2.28 -3,203.49 MWD+IFR-AK-CAZ-SC(3) 12/13/2016 12:30:16PM Page 4 COMPASS 5000.1 Build 74 • Sp Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 l Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,915.39 54.45 296.32 5,269.39 5,110.29 -1,665.41 -4,774.23 5,928,045.37 1,616,153.38 3.77 -3,197.86 MWD+IFR-AK-CAZ-SC(3) 8,007.47 55.41 299.86 5,322.31 5,163.21 -1,629.92 -4,840.69 5,928,081.02 1,616,087.02 3.31 -3,187.24 MWD+IFR-AK-CAZ-SC(3) 8,100.49 55.39 303.20 5,375.14 5,216.04 -1,589.89 -4,905.94 5,928,121.22 1,616,021.88 2.96 -3,171.94 MWD+IFR-AK-CAZ-SC(3) 8,193.07 55.44 306.84 5,427.71 5,268.61 -1,546.17 -4,968.34 5,928,165.10 1,615,959.59 3.24 -3,152.19 MWD+IFR-AK-CAZ-SC(3) 8,286.09 55.80 309.81 5,480.24 5,321.14 -1,498.56 -5,028.55 5,928,212.86 1,615,899.51 2.66 -3,128.06 MWD+IFR-AK-CAZ-SC(3) 8,380.27 57.04 309.97 5,532.33 5,373.23 -1,448.24 -5,088.76 5,928,263.32 1,615,839.44 1.32 -3,101.36 MWD+IFR-AK-CAZ-SC(3) 8,473.31 56.71 309.14 5,583.17 5,424.07 -1,398.62 -5,148.83 5,928,313.10 1,615,779.50 0.83 -3,075.28 MWD+IFR-AK-CAZ-SC(3) 8,564.64 55.84 310.08 5,633.88 5,474.78 -1,350.20 -5,207.35 5,928,361.67 1,615,721.11 1.28 -3,049.79 MWD+IFR-AK-CAZ-SC(3) 8,659.27 55.94 311.96 5,686.95 5,527.85 -1,298.78 -5,266.46 5,928,413.23 1,615,662.14 1.65 -3,021.69 MWD+IFR-AK-CAZ-SC(3) 8,752.97 57.18 315.11 5,738.59 5,579.49 -1,244.92 -5,323.12 5,928,467.23 1,615,605.63 3.10 -2,990.46 MWD+IFR-AK-CAZ-SC(3) 8,87.00-58 26 317.39 5,788.82 5,629.72 -1,187.50 -5,378.08 5.928,524.79 1,615,550.82 2.35 -2,955.29 NOT anActual Survey � L_. 10-3/4"x 13-1/2"-Top of 10-3/4"casino Window . , II 8,867.00 60.11 316.14 5.799.06 5,639.96 -1,174.99 -5,389.85 5,928,537.33 1,615,539.09 10.69 -2.947.56 INC+TREND(4) 8,938.22 60.40 318.61 5,834.40 5,675.30 -1,129.49 -5,431.72 5,928,582.93 1,615,497.34 3.04 -2,919.13 INC+TREND(4) 9,033.16 61.50 321.89 5,880.51 5,721.41 -1,065.69 -5,484.77 5,928,646.87 1,615,444.46 3.23 -2,877.32 INC+TREND(4) 9,128.47 63.09 325.16 5,924.83 5,765.73 -997.84 -5,534.90 5,928,714.84 1,615,394.51 3.47 -2,830.71 INC+TREND(4) 9,224.66 63.51 328.41 5,968.06 5,808.96 -925.95 -5,581.96 5,928,786.83 1,615,347.64 3.05 -2,779.26 INC+TREND(4) 9,318.30 62.62 331.53 6,010.48 5,851.38 -853.70 -5,623.74 5,928,859.19 1,615,306.05 3.12 -2,725.65 MWD+IFR-AK-CAZ-SC(5) 9,375.23 63.12 332.63 6,036.44 5,877.34 -808.93 -5,647.46 5,928,904.02 1,615,282.44 1.93 -2,691.69 MWD+IFR-AK-CAZ-SC(5) 9,412.83 63.99 333.29 6,053.19 5,894.09 -778.94 -5,662.77 5,928,934.04 1,615,267.22 2.80 -2,668.75 MWD+IFR-AK-CAZ-SC(5) 9,461.94 65.63 334.82 6,074.09 5,914.99 -738.98 -5,682.21 5,928,974.05 1,615,247.89 4.37 -2,637.85 MWD+IFR-AK-CAZ-SC(5) 9,507.98 65.70 334.76 6,093.06 5,933.96 -701.03 -5,700.07 5,929,012.04 1,615,230.12 0.19 -2,608.29 MWD+IFR-AK-CAZ-SC(5) 9,602.61 66.32 333.71 6,131.54 5,972.44 -623.17 -5,737.66 5,929,089.99 1,615,192.74 1.21 -2,547.98 MWD+IFR-AK-CAZ-SC(5) 9,647.82 66.88 333.74 6,149.49 5,990.39 -585.97 -5,756.02 5,929,127.24 1,615,174.47 1.24 -2,519.30 MWD+IFR-AK-CAZ-SC(5) 9,696.77 67.55 333.33 6,168.45 6,009.35 -545.57 -5,776.14 5,929,167.68 1,615,154.47 1.57 -2,488.22 MWD+IFR-AK-CAZ-SC(5) 9,791.94 67.87 336.22 6,204.55 6,045.45 -465.92 -5,813.66 5,929,247.42 1,615,117.15 2.83 -2,426.20 MWD+IFR-AK-CAZ-SC(5) 9,886.71 68.93 339.38 6,239.45 6,080.35 -384.34 -5,846.94 5,929,329.07 1,615,084.09 3.30 -2,360.93 MWD+IFR-AK-CAZ-SC(5) 9,981.86 71.62 341.84 6,271.56 6,112.46 -299.87 -5,876.65 5,929,413.62 1,615,054.60 3.73 -2,291.72 MWD+IFR-AK-CAZ-SC(5) 10,076.71 74.36 344.43 6,299.31 6,140.21 -213.08 -5,902.95 5,929,500.46 1,615,028.53 3.89 -2,219.16 MWD+IFR-AK-CAZ-SC(5) 10,171.00 78.01 345.70 6,321.83 6,162.73 -124.63 -5,926.53 5,929,588.97 1,615,005.17 4.09 -2,144.10 MWD+IFR-AK-CAZ-SC(5) 10,265.91 81.96 347.61 6,338.33 6,179.23 -33.71 -5,948.09 5,929,679.94 1,614,983.85 4.61 -2,066.04 MWD+IFR-AK-CAZ-SC(5) 10,350.09 85.54 348.73 6,347.49 6,188.39 48.18 -5,965.24 5,929,761.86 1,614,966.92 4.45 -1,994.95 MWD+IFR-AK-C6Z-SC(5) ` 10,410.00 87.66 350.32 6,351.05 6,191.95 106.99 -5,976.11 5,929,820.69 1,614,956.20 4.42 -1,943.41 INOT an Actual Survey, 7-5/8"x 9-7/8" I 10,439.96 88.72 351.12 6,351.99 6,192.89 136.54 -5,980.93 5,929,850.25 1,614,951.45 4.42 -1,917.30 MWD+IFR-AK-CAZ-SC(6) 10,535.42 91.10 353.56 6,352.14 6,193.04 231.13 -5,993.66 5,929,944.87 1,614,938.97 3.57 -1,832.76 MWD+IFR-AK-CAZ-SC(6) 10,629.83 92.61 355.61 6,349.09 6,189.99 325.06 -6,002.56 5,930,038.81 1,614,930.31 2.70 -1,747.54 MWD+IFR-AK-CAZ-SC(6) 10,724.25 92.92 0.19 6,344.53 6,185.43 419.29 -6,006.02 5,930,133.03 1,614,927.10 4.86 -1,660.18 MWD+IFR-AK-CAZ-SC(6) 10,819.52 93.12 3.70 6,339.51 6,180.41 514.35 -6,002.79 5,930,228.08 1,614,930.57 3.69 -1,569.74 MWD+IFR-AK-CAZ-SC(6) 10,913.73 92.54 6.90 6,334.86 6,175.76 608.03 -5,994.10 5,930,321.73 1,614,939.50 3.45 -1,478.74 MWD+IFR-AK-CAZ-SC(6) 12/13/2016 12:30:16PM Page 5 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 11,008.58 91.57 11.24 6,331.45 6,172.35 701.61 -5,979.16 5,930,415.26 1,614,954.68 4.69 -1,385.69 MWD+IFR-AK-CAZ-SC(6) 11,103.97 91.78 14.68 6,328.66 6,169.56 794.52 -5,957.78 5,930,508.10 1,614,976.30 3.61 -1,291.07 MWD+IFR-AK-CAZ-SC(6) 11,198.72 91.89 18.27 6,325.63 6,166.53 885.32 -5,930.92 5,930,598.82 1,615,003.39 3.79 -1,196.57 MWD+IFR-AK-CAZ-SC(6) 11,293.57 92.68 19.08 6,321.85 6,162.75 975.10 -5,900.58 5,930,688.52 1,615,033.96 1.19 -1,101.82 MWD+IFR-AK-CAZ-SC(6) 11,388.82 92.12 18.72 6,317.86 6,158.76 1,065.14 -5,869.75 5,930,778.46 1,615,065.02 0.70 -1,006.67 MWD+IFR-AK-CAZ-SC(6) 11,483.52 92.63 18.77 6,313.93 6,154.83 1,154.74 -5,839.35 5,930,867.98 1,615,095.65 0.54 -912.08 MWD+IFR-AK-CAZ-SC(6) 11,577.75 90.23 19.57 6,311.58 6,152.48 1,243.71 -5,808.42 5,930,956.86 1,615,126.81 2.68 -817.89 MWD+IFR-AK-CAZ-SC(6) 11,673.11 89.06 19.46 6,312.17 6,153.07 1,333.59 -5,776.56 5,931,046.64 1,615,158.89 1.23 -722.54 MWD+IFR-AK-CAZ-SC(6) 11,767.34 89.06 18.28 6,313.72 6,154.62 1,422.74 -5,746.09 5,931,135.71 1,615,189.59 1.25 -628.34 MWD+IFR-AK-CAZ-SC(6) 11,862.17 90.17 17.52 6,314.36 6,155.26 1,512.97 -5,716.94 5,931,225.86 1,615,218.97 1.42 -533.58 MWD+IFR-AK-CAZ-SC(6) 11,957.60 90.48 16.29 6,313.81 6,154.71 1,604.28 -5,689.20 5,931,317.08 1,615,246.95 1.33 -438.29 MWD+IFR-AK-CAZ-SC(6) 12,051.62 90.34 14.65 6,313.14 6,154.04 1,694.88 -5,664.12 5,931,407.62 1,615,272.25 1.75 -344.57 MWD+IFR-AK-CAZ-SC(6) 12,146.27 90.65 13.51 6,312.32 6,153.22 1,786.69 -5,641.09 5,931,499.35 1,615,295.51 1.25 -250.43 MWD+IFR-AK-CAZ-SC(6) 12,240.60 90.72 12.99 6,311.20 6,152.10 1,878.50 -5,619.48 5,931,591.09 1,615,317.37 0.56 -156.76 MWD+IFR-AK-CAZ-SC(6) 12,334.63 91.10 12.43 6,309.70 6,150.60 1,970.21 -5,598.79 5,931,682.75 1,615,338.29 0.72 -63.51 MWD+IFR-AK-CAZ-SC(6) 12,429.40 91.23 14.01 6,307.78 6,148.68 2,062.45 -5,577.12 5,931,774.92 1,615,360.19 1.67 30.58 MWD+IFR-AK-CAZ-SC(6) 12,523.32 90.61 14.69 6,306.27 6,147.17 2,153.42 -5,553.85 5,931,865.82 1,615,383.70 0.98 124.03 MWD+IFR-AK-CAZ-SC(6) 12,617.71 90.99 15.51 6,304.95 6,145.85 2,244.55 -5,529.26 5,931,956.87 1,615,408.52 0.96 218.06 MWD+IFR-AK-CAZ-SC(6) 12,713.41 90.75 15.71 6,303.50 6,144.40 2,336.71 -5,503.51 5,932,048.96 1,615,434.50 0.33 313.47 MWD+IFR-AK-CAZ-SC(6) 12,807.98 91.27 16.49 6,301.83 6,142.73 2,427.55 -5,477.29 5,932,139.72 1,615,460.95 0.99 407.81 MWD+IFR-AK-CAZ-SC(6) 12,903.10 91.30 16.20 6,299.70 6,140.60 2,518.80 -5,450.53 5,932,230.90 1,615,487.95 0.31 502.71 MWD+IFR-AK-CAZ-SC(6) 12,997.68 91.71 16.65 6,297.21 6,138.11 2,609.49 -5,423.80 5,932,321.51 1,615,514.91 0.64 597.07 MWD+IFR-AK-CAZ-SC(6) 13,092.51 91.85 16.59 6,294.27 6,135.17 2,700.32 -5,396.68 5,932,412.25 1,615,542.26 0.16 691.69 MWD+IFR-AK-CAZ-SC(6) 13,187.36 91.09 14.95 6,291.83 6,132.73 2,791.56 -5,370.92 5,932,503.42 1,615,568.26 1.91 786.25 MWD+IFR-AK-CAZ-SC(6) 13,282.41 91.54 14.65 6,289.65 6,130.55 2,883.43 -5,346.64 5,932,595.22 1,615,592.77 0.57 880.88 MWD+IFR-AK-CAZ-SC(6) 13,376.96 91.68 13.95 6,287.00 6,127.90 2,975.02 -5,323.30 5,932,686.74 1,615,616.34 0.75 974.93 MWD+IFR-AK-CAZ-SC(6) 13,472.42 91.65 13.72 6,284.22 6,125.12 3,067.67 -5,300.48 5,932,779.32 1,615,639.40 0.24 1,069.80 MWD+IFR-AK-CAZ-SC(6) 13,567.08 91.85 12.99 6,281.33 6,122.23 3,159.73 -5,278.63 5,932,871.31 1,615,661.49 0.80 1,163.77 MWD+IFR-AK-CAZ-SC(6) 13,661.67 91.92 13.17 6,278.22 6,119.12 3,251.81 -5,257.23 5,932,963.33 1,615,683.12 0.20 1,257.62 MWD+IFR-AK-CAZ-SC(6) 13,756.58 91.72 14.02 6,275.21 6,116.11 3,344.02 -5,234.93 5,933,055.47 1,615,705.65 0.92 1,351.89 MWD+IFR-AK-CAZ-SC(6) 13,851.57 91.04 14.42 6,272.92 6,113.82 3,436.07 -5,211.61 5,933,147.45 1,615,729.22 0.83 1,446.37 MWD+IFR-AK-CAZ-SC(6) I 13,945.61 88.46 14.61 6,273.33 6,114.23 3,527.10 -5,188.04 5,933,238.41 1,615,753.02 2.75 1,539.97 MWD+IFR-AK-CAZ-SC(6) 14,039.92 86.30 13.63 6,277.64 6,118.54 3,618.46 -5,165.06 5,933,329.70 1,615,776.23 2.51 1,633.68 MWD+IFR-AK-CAZ-SC(6) 14,134.35 87.29 13.68 6,282.92 6,123.82 3,710.07 -5,142.80 5,933,421.25 1,615,798.72 1.05 1,727.39 MWD+IFR-AK-CAZ-SC(6) 14,229.07 87.22 13.73 6,287.46 6,128.36 3,801.99 -5,120.38 5,933,513.10 1,615,821.37 0.09 1,821.43 MWD+IFR-AK-CAZ-SC(6) 14,323.19 87.19 13.00 6,292.04 6,132.94 3,893.45 -5,098.65 5,933,604.50 1,615,843.34 0.78 1,914.80 MWD+IFR-AK-CAZ-SC(6) 14,417.40 88.04 13.48 6,295.97 6,136.87 3,985.08 -5,077.10 5,933,696.06 1,615,865.13 1.04 2,008.28 MWD+IFR-AK-CAZ-SC(6) 14,512.01 88.42 14.13 6,298.89 6,139.79 4,076.91 -5,054.53 5,933,787.82 1,615,887.93 0.80 2,102.29 MWD+IFR-AK-CAZ-SC(6) 14,606.89 87.98 15.06 6,301.87 6,142.77 4,168.68 -5,030.63 5,933,879.52 1,615,912.06 1.08 2,196.70 MWD+IFR-AK-CAZ-SC(6) 14,701.10 88.06 15.99 6,305.12 6,146.02 4,259.40 -5,005.43 5,933,970.17 1,615,937.49 0.99 2,290.57 MWD+IFR-AK-CAZ-SC(6) 12/13/2016 12:30::16PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: 2S-13A actual @ 159.10usft(Doyon 142) Well: 2S-13 North Reference: True Wellbore: 2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13A Database: OAKEDMP2 I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 14,796.86 90.15 16.94 6,306.62 6,147.52 4,351.21 -4,978.30 5,934,061.90 1,615,964.86 2.40 2,386.13 MWD+IFR-AK-CAZ-SC(6) 14,890.11 89.90 18.40 6,306.58 6,147.48 4,440.06 -4,949.99 5,934,150.67 1,615,993.39 1.59 2,479.30 MWD+IFR-AK-CAZ-SC(6) 14,985.25 90.40 17.40 6,306.33 6,147.23 4,530.59 -4,920.75 5,934,241.12 1,616,022.87 1.18 2,574.37 MWD+IFR-AK-CAZ-SC(6) 15,081.04 92.14 18.38 6,304.21 6,145.11 4,621.73 -4,891.34 5,934,332.16 1,616,052.51 2.08 2,670.07 MWD+IFR-AK-CAZ-SC(6) 15,176.99 91.99 19.58 6,300.75 6,141.65 4,712.40 -4,860.15 5,934,422.74 1,616,083.93 1.26 2,765.94 MWD+IFR-AK-CAZ-SC(6) 15,266.87 92.23 20.48 6,297.44 6,138.34 4,796.78 -4,829.39 5,934,507.04 1,616,114.91 1.04 2,855.76 MWD+IFR-AK-CAZ-SC(6) 15,360.63 91.75 19.36 6,294.18 6,135.08 4,884.88 -4,797.46 5,934,595.05 1,616,147.06 1.30 2,949.46 MWD+IFR-AK-CAZ-SC(6) 15,452.95 91.92 17.63 6,291.23 6,132.13 4,972.38 -4,768.19 5,934,682.46 1,616,176.55 1.88 3,041.69 MWD+IFR-AK-CAZ-SC(6) 15,545.52 91.58 15.86 6,288.40 6,129.30 5,060.98 -4,741.53 5,934,770.99 1,616,203.43 1.95 3,134.07 MWD+IFR-AK-CAZ-SC(6) 15,638.03 91.37 14.43 6,286.02 6,126.92 5,150.25 -4,717.37 5,934,860.18 1,616,227.82 1.56 3,226.21 MWD+IFR-AK-CAZ-SC(6) 15,731.19 91.68 13.56 6,283.54 6,124.44 5,240.61 -4,694.85 5,934,950.47 1,616,250.57 0.99 3,318.83 MWD+IFR-AK-CAZ-SC(6) 15,823.03 92.33 12.64 6,280.33 6,121.23 5,330.00 -4,674.05 5,935,039.80 1,616,271.61 1.23 3,409.95 MWD+IFR-AK-CAZ-SC(6) 15,914.11 91.82 12.39 6,277.03 6,117.93 5,418.86 -4,654.33 5,935,128.60 1,616,291.56 0.62 3,500.19 MWD+IFR-AK-CAZ-SC(6) 16,007.20 92.07 13.43 6,273.87 6,114.77 5,509.54 -4,633.54 5,935,219.22 1,616,312.57 1.15 3,592.51 MWD+IFR-AK-CAZ-SC(6) 16,097.95 90.35 14.16 6,271.95 6,112.85 5,597.65 -4,611.91 5,935,307.27 1,616,334.43 2.06 3,682.71 MWD+IFR-AK-CAZ-SC(6) 16,189.55 91.47 15.39 6,270.50 6,111.40 5,686.21 -4,588.55 5,935,395.75 1,616,358.02 1.82 3,773.91 MWD+IFR-AK-CAZ-SC(6) 16,281.22 91.82 18.29 6,267.86 6,108.76 5,773.90 -4,562.01 5,935,483.37 1,616,384.78 3.19 3,865.40 MWD+IFR-AK-CAZ-SC(6) 16,372.57 91.61 20.89 6,265.13 6,106.03 5,859.92 -4,531.40 5,935,569.30 1,616,415.61 2.85 3,956.69 MWD+IFR-AK-CAZ-SC(6) 16,465.96 91.75 21.04 6,262.39 6,103.29 5,947.09 -4,498.00 5,935,656.37 1,616,449.24 0.22 4,050.03 MWD+IFR-AK-CAZ-SC(6) 16,557.37 91.99 21.05 6,259.41 6,100.31 6,032.36 -4,465.19 5,935,741.55 1,616,482.26 0.26 4,141.38 MWD+IFR-AK-CAZ-SC(6) 16,649.73 91.96 20.73 6,256.23 6,097.13 6,118.59 -4,432.27 5,935,827.69 1,616,515.39 0.35 4,233.67 MWD+IFR-AK-CAZ-SC(6) 16,742.46 91.34 20.53 6,253.56 6,094.46 6,205.34 -4,399.62 5,935,914.34 1,616,548.27 0.70 4,326.36 MWD+IFR-AK-CAZ-SC(6) 16,833.45 91.20 21.13 6,251.54 6,092.44 6,290.36 -4,367.27 5,935,999.27 1,616,580.84 0.68 4,417.31 MWD+IFR-AK-CAZ-SC(6) 16,856.69 91.34 21.19 6,251.02 6,091.92 6,312.03 -4,358.88 5,936,020.92 1,616,589.28 0.66 4,440.54 MWD+IFR-AK-CAZ-SC(6) L216,907.00 91.34 .19 6,249.85 6,090.75 6,358.93 -4,340.70 5,936,067.76 1,616,607.58 0.00 4,490.83 NOT an Actual Survey 4 1/2"x 6-3/4" 16,917.00 91.34 21.19 6,249.61 6,090.51 6,368.25 -4,337.09 5,936,077.07 1,616,611.21 0.00 4,500.82 PROJECTED to TD 12/13/2016 12:30:16PM Page 7 COMPASS 5000.1 Build 74 • Final Definitive Survey Verified and Signed-off All targets and:'or well position objectives have been achieved. Lues L No I have checked to the best of my ability that the following data is correct: Surface Coordinates A Declination & Convergence E] GRS Survey Corrections J] Survey Tool Codes r.eYdt,yvr�.m - ohara DN s-„Ymm+:airtt Vincent Osara SLB DE: o�.aeu. 2.14 0914s t19 t, Diglialyaavdt•+state erV.Ida Scott Brunswick Client Representative: RQv WWI:,1004:31S34 O➢DJ Date 14-Dec-2016 • • 216104 27 8 0 0 RECEIVED DEC 08 2016 COnOCOPhilliPS AOGCC TRANSMITTAL FROM: Sandra D. Lemke, ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 DATA LOGGED RE: 2S-13A aivatizo-igy DATE: 12/07/2016 M.K.BENDER Transmitted: Kuparuk River Unit, Alaska 2S-13A 1 CD & 1 log image each with .las exports 1 color print each Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCiConocophi//ips,com CC: 2S-13A transmittal folder, production well files, eSearch Receipt:/a < ,<< /� ,/ate: Tr .� x. GIS-Technical Data Management I ConocoPhillips I Anchorage,Alaska I Ph:907.265.6947 4110 • PTO 216,- 101-, Loepp, Victoria T (DOA) From: Kanady, Randall B <Randall.B.Kanady@conocophillips.com> Sent: Thursday, October 27, 2016 2:10 PM To: Loepp,Victoria T(DOA) Cc: Brunswick, Scott A;Quick, Michael J (DOA) Subject: RE:2S-13 Sundry 316-468&2S-13 L1 316-431 Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for taking another look at this. Randy From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,October 27,2016 1:44 PM To: Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Cc: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com>;Quick, Michael J (DOA)<michael.quick@alaska.gov> Subject: [EXTERNAL]RE: 2S-13 Sundry 316-468&2S-13 L1 316-431 Randy,Scott, The tag of TOC in step 18a is not required. 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.Loeppalaska.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.Loeop@alaska.gov From: Kanady, Randall B [mailto:Randall.B.Kanady@conocophillips.com] Sent:Thursday,October 27, 2016 11:45 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Quick, Michael J (DOA)<michael.quick@alaska.gov> Cc: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com>; Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Subject: RE:2S-13 Sundry 316-468&2S-13 L1 316-431 1 • • Victoria/Mike, Attached is the 2S-13 10-403 approved plug. As Scott said below we would like to cancel performing step 18.a WOC to tag(notify AOGCC for opportunity to witness tag of cement) The pressure test in Step 19 will check&ensure the integrity of the cement abandonment&retainer combination. We would like to forgo the tag of the cement if allowed. Because we are using a cement retainer we believe we are meeting the requirements of 20 AAC 25.112(g) (listed below). If we were not using a cement retainer then a tag of top of cement would be required/appropriate. 20 AAC 25.112(g) Except for surface plugs,the operator shall record the actual location and integrity of cement plugs, cement retainers, or bridge plugs required by this section, using one of the following methods,which in the case of a cement retainer or bridge plug may be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place; (2)testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. We are not trying to cut out any required steps,just trying to be as efficient with our rig time as possible. Can you please reconsidered this request and let us know your determination. Thank you for your time, Randy Randall Kanady P.E. ConocoPhillips Alaska Drilling and Wells Office: 907-263-4126 Cell:907-575-0742 randall.b.kanady@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,October 26, 2016 8:55 AM To: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 2S-13 Sundry 316-468&2S-13 L1 316-431 Scott, A tag is required in addition to the pressure test. 2 i 411/ 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[e 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.Loepp@alaska.gov From: Brunswick,Scott A[mailto:Scott.A.Brunswick@conocophillips.com] Sent:Tuesday,October 25,2016 8:34 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Subject:2S-13 Sundry 316-468&25-13 L1 316-431 Victoria Please refer to the subject line approved sundries. I was talking about plans on the upcoming 2S-13 abandonment with co-workers and was informed step 18.a in the sundry procedure may not be required as we plan to perform a pressure test above the cement retainer once the cement squeeze has been performed,cement cap placed,and stung out of the cement retainer. Is the above a correct statement,and may we cancel performing step 18.a (WOC to tag(notify AOGCC for opportunity to witness tag of cement) I believe the pressure test will check&ensure the integrity of the cement abandonment& retainer combination and would like to forgo the tag of the cement if allowed. Thanks Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) 3 Carlisle, Samantha J (DOA) From: Loepp,Victoria T (DOA) Sent: Friday, October 07, 2016 10:39 AM To: Carlisle, Samantha J (DOA) Cc: Bettis, Patricia K(DOA) Subject: FW: 2S-13A(PTD 216-104) &2S-13A Ll (PTD 216-105) Attachments: RE: 2S-13A (PTD 216-104) &2S-13A Ll (PTD 216-105) Sam, Please handle. Thanx, Victoria From: Brunswick,Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Friday,October 07, 2016 10:36 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>; Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: 2S-13A(PTD 216-104) &2S-13A L1 (PTD 216-105) Victoria I would like to withdraw the 2 "change to approved permit to drill" applications I sent over the other day that reflected the change toe location of both lateral as this matter has now been handled via e-mail. Thank you Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) 1 Carlisle, Samantha J (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, October 07, 2016 10:01 AM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: 2S-13A(PTD 216-104) &2S-13A Ll (PTD 216-105) Please see below, I also sent over a packet with a cover letter for an update to approved drilling program just to be on the safe side,of course that was before I found out the current well is going to delay the next by a few weeks. 2S-13A New Toe location: 4a. Location of Well(Governmental Section): Surface: 3099.9'FNL, 1672.2'FEL,SEC17,T1ON, R8E, UM Top of Productive Horizon: 3079.5 FNL,2320.4'FEL,SEC18,T1ON, R8E, UM Total Depth: 1980.9'FNL,701.97'FEL,SEC7,T1ON, R8E, UM Location at Total Depth 1 1980.9' FNL, 701.97' FEL, Sec 7,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 16,914' Northings: 5,936,359.35' Eastings: 476,585.68' Total Vertical Depth, RKB: 6,249' Total Vertical Depth, SS: 6,090' 2S-13A 11. 4a. Location of Well(Governmental Section): Surface: 3099.9'FNL, 1672.2'FEL,SEC17,T1ON, R8E,UM Top of Productive Horizon: 3381.9'FNL,2269.5'FEL,SEC18,T1ON, R8E, UM Total Depth: 1943.3'FNL,828.97'FEL,SEC7,T1ON, R8E, UM Location at Total Depth 1 1943.3' FNL, 828.97' FEL, Sec 7,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 17,023' Northings: 5,936,397.35' Eastings:476,458.68' Total Vertical Depth, RKB: 6,215' Total Vertical Depth, SS: 6,056' Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) 1 i 0 From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Friday,October 07, 2016 9:55 AM To: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: 2S-13A(PTD 216-104) &2S-13A L1 (PTD 216-105) Scott, Please provide new coordinates and footage from section lines in an email and the PTD will be updated. No need to submit a revised PTD,the email will suffice. Thanx, Victoria From: Brunswick,Scott A[mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday,October 03, 2016 4:14 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: 2S-13A(PTD 216-104) &2S-13A L1 (PTD 216-105) Victoria G&G changed the toe location on the subject line wellbores. They both moved less than 500 ft to the east of the location submitted in the approved PTD's. I've created an updated permit pack that I can send over if it is required. All the same material,the only change is the updated TD coordinates. Original Toe: TD Co-ordinates: 2S-13A: 1911' FNL, 852' FEL, Sec 7,T1ON, RO8E, UM 2S-13A L1: 1894' FNL, 959' FEL, Sec 7,T1ON, RO8E, UM Updated Toe: TD Co-ordinates: 2S-13A: 1980.9' FNL, 701.97' FEL, Sec 7,T1ON, RO8E, UM 2S-13A L1: 1943.27' FNL, 828.97' FEL,Sec 7,T1ON, RO8E, UM Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) 2 • pro 2,1(0- 104 14'10-,- Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Monday, October 03, 2016 4:14 PM To: Loepp,Victoria T(DOA) Subject: 2S-13A(PTD 216-104) &2S-13A Li (PTD 216-105) Follow Up Flag: Follow up Flag Status: Flagged Victoria G&G changed the toe location on the subject line wellbores. They both moved less than 500 ft to the east of the location submitted in the approved PTD's. I've created an updated permit pack that I can send over if it is required. All the same material,the only change is the updated TD coordinates. Original Toe: TD Co-ordinates: 2S-13A: 1911' FNL,852'FEL,Sec 7,T1ON, RO8E, UM 2S-13A L1: 1894' FNL,959'FEL,Sec 7,T1ON, RO8E, UM Updated Toe: TD Co-ordinates: 2S-13A: 1980.9' FNL,701.97' FEL,Sec 7,T1ON, RO8E, UM 2S-13A L1: 1943.27' FNL,828.97'FEL,Sec 7,T1ON, RO8E, UM Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) 1 OCT 0 6 2°16 STATE OF ALASKA lEVIS EA AIDA OIL AND GAS CONSERVATION COMMIOJN AOGCO PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj 0 Single Zone 0 Coalbed Gas ❑ Gas ydrates ❑ Redrill 0 Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ •ale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name a . Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-13A 3.Address: 6.Proposed Depth: 12.Feld/Polls): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16958' TVD: 6249' p•rr, River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3099.9'FNL, 1672.2'FEL,SEC17,T1ON,R8E, UM ADL 25603,25590 •"i aruk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 0 ,,' 13.Approximate Spud Date: 3079.5'FNL,2320.4'FEL,SEC18,T1ON,R8E, UM 2677,2678,2675 10/8/2016 Total Depth: 9.Acres in Property: \ 14.Distance to Nearest Property: 1980.9'FNL,701.97'FEL,SEC7,T1 ON,R8E,UM 2512,2501 / 2741.5'from ADL380051 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL( :(// 158.5 15.Distance to Nearest Well Open Surface: x-480,898.10' y-5,929,948.79' Zone-4 GL Elevation above SL ): 119.8 to Same Pool: 1683.7'f/2S-14 16.Deviated wells: Kickoff depth: 9138 feet 17.Maximum Potential Pr s in psig(see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3840 Surface: 3209 18.Casing Program: Specifications Top - Setti . =pth - Botto Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD •. 4TVD (including stage data) 9.875 7.625 29.7 L-80 HYD563 10277' 39' 39' ' 103 6332' 353 sx 15.8 ppg Class G 6.75 4.5 12.6 L-80 IBTM 6714' 10200' 6'p,-.... 169 4' 6249' N/A 19. PRESENT WELL CONDITION SUMMARY(To be co -.,etilf • r •e.rill and Re-Entry Operations) ) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): / E t.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 16878.5 6216.9 RHC 9758 / 9926.5 6261.5 9926.5 Casing Length Size / dement Volume MD TVD Conductor/Structural 78' 20" 1���/ \\ 117.5' 117.5' Surface 2807.7' 13.375" `I :.1 sx 11.0 ppg&278 sx 12 ppg 2847.1' 2559.3' Intermediate 6631.84' 10.75" 1/ \ 1 .5 sx 15.8 ppg Class G 9329.5' Production 10407.83' 7.625" �8 sx 15.8 6029.5' � ppg class G 10445.72' 6331.5' Liner 6860.34' 4.5" !' 4/A 16841.11' 6245.5' Perforation Depth MD(ft): N/A / Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat ❑ B4-N h ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Div-.-r =tch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements2 21. Verbal Approval: Commission Representative: /Date [ b- 3'(d- 5o/ 22. I hereby certify that the foregoing is true and the . .cedure approved herein will not Scott Brunswick 263-4249 be deviated from without prior written approval. Contact scott.a.brunswickt cop.com Email Printed Name G.Chip Alvord Title AK Drilling Manager Signature /4_ c. oA Phone 265-6120 Date 1,0(512_/(0 Commission Use Only Permit to Drill A'I Number: Permit Approval See cover letter for other Number:,,,(_V. t e„t:Sed, 50- -2.07 2_0 103 "01-UG Date: c .((a _2.0((4. requirements. Conditions of approval: If bo is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd:Yes❑ No❑ H2S measures: Yes❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: D G COMMISSIONER THE COMMISSION Date: 1 \ t Submit Form and Form 10-401(Revised 11/2015) �rneess Iplennnnnn!!![[[ from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-13A Saved:3-Oct-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 •11 Phone(907)263-4249 ips Email: scott.a.brunswickAconocophillips.com October 3,2016 ESV ED Alaska Oil and Gas Conservation Commission (QCT 0 6 2016 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 AOGC Re: Application for change to approved Permit to Drill Well 2S-13A A3 Sand Pre-Produced Injector(PTD 216-104). Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an update to an approved permit to re-drill of an onshore pre-produced injector well from the 2S pad(PTD#216-104). The expected spud date for this well is October 8,2016. It is planned to use rig Doyon 142. This changed it to the final TD of the lower Kuparuk A3 lateral,moving the toe to the east. The coordinates of the well from the intermediate#2 7-5/8"casing point to surface remain the same as in the approved PTD. Attached here-in find the paperwork with updated TD coordinates&depths. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 (scott.a.brunswick@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer S Application for Permit to Drill Document &MOUS Kuparuk Well 2S-13A ConocoPhilips Well Name Requirements of 20 AAC 25.005(1) The well for which this application is submitted will be designated as 2S-13A Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation.and at total depth.referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3099.9' FNL, 1672.22 FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 159'AMSL Northings: 5,929,948.8' Eastings: 480,898.1' Pad Elevation 120'AMSL Location at Surface Casing 3728.0'FNL,2414.4'FEL, Sec 17,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 2,847' Northings: 5,929,322.6' Eastings: 480,156.3' Total Vertical Depth, RKB: 2,559' Total Vertical Depth, SS: 2,400' Location at 10-3/4" 3728.0' FNL,2414.4' FEL, Sec 17,T1ON,R008E,UM whipstock in Intermediate#1 10-3/4"Liner NGS Coordinates Measured Depth, RKB: 9,138' Northings: 5,928,946.86' Eastings: 475,384.67' Total Vertical Depth, RKB: 5,937' Total Vertical Depth, SS: 5,778' Location at Intermediate#2 3079.51' FNL,2320.4' FEL, Sec 18,T1ON,R008E,UM 7-5/8"Casing NGS Coordinates Measured Depth, RKB: 10,316' Northings: 5,929,986.50' Eastings: 474,970.55' Total Vertical Depth, RKB: 6,332' Total Vertical Depth, SS: 6,173' Location at Total Depth 1980.9' FNL, 701.97' FEL, Sec 7,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 16,914' Northings: 5,936,359.35' Eastings: 476,585.68' Total Vertical Depth, RKB: 6,249' Total Vertical Depth, SS: 6,090' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. • The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-13A is calculated using an estimated maximum reservoir pressure of 3,840 psi (11.7 ppg, based on MPD draw down test of 2S-13 toe), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,312' TVD: A Sand Estimated. BHP = 3,840 psi A Sand estimated depth = 6,312' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 631 psi (6,312' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,209 psi (3,840 psi—631 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-13A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) ��) t(lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 36 78.7 H-40 Welded 78 Surf 117.5'117.5' Pre-installed&cemented Hydril2847.1'/ Existing cement to Surface with 13-3/8 16 68 L-80 563 2807.7' Surf 2559.3' 1460 sx Lead 11.0 ppg, 278 sx Tail Slurry 12.0 ppg 12-1/4 Hydril9329.5'/ Existing cement to above C-37 10-3/4 x 13- 45.5 L-80 521 6631.8' 2697'/2449' 6029.5' 1535 sx 15.8 ppg Class G 1/2 7-5/8 9-7/8 29.7 L-80 Hydril 10 277' Surf 10,316/6,332 Cement to inside 10-3/4"liner 563 353 sx 15.8 ppg Class G 4-1/2 6-3/4 12.6 L-80 IBTM 6,714 10,200/6,314 16,914/6,249 N/A Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Surface hole has been drilled, BOPE will be installed. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Intermediate#2 Production 9-7/8" Hole 6-3/4" Hole 7-5/8" Liner& 4-1/2"Liner Tieback Flo-Thru Mud System LSND(WBM) (WBM) Density 10.5-11.8 10.5-11.8 PV 10-20 25 - 30 YP 16 -24 16—24 Initial Gel 10- 12 5—8 lO minute Gel 10 - 18 5 - 12 API Filtrate <6 <6 HTHP Fluid Loss at 160F < 10 < 10 pH 9.0- 10.0 9.5 - 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. • • 1. End sundry to plug for re-drill(Sundry 316-468&316-431) 2. Orient&begin sidetracking to drill the landing intermediate section of 2S-13A. 3. Directionally drill to intermediate#2 hole TD of 10,316'MD/6,332' TVD landing in the Kuparuk A3 sand. 3.3.1.Utilize MPD to hold constant bottom hole pressure. 4. Circulate&rotate at maximum rates until shakers are clean with minimum of 3 bottoms up. 3.4.1.Perform MPD draw down formation pressure test&eight up mud system to kill weight as necessary. 5. Drop rabbit with 120' tail sling for liner run. 6. POOH on elevators racking back 5"drill pipe. (lay 5"DP down after the upcoming 7-5/8"liner run,this will minimize shale exposure time.) 7. Lay down intermediate BHA. 8. Swap out upper pipe rams for 7-5/8"solid body rams&test, 3500 psi high,250 psi low. 9. Run 7-5/8",29.7#L80,Hydril 563 liner. 10. Make up 7-5/8"liner hanger&fill liner tieback with"pal mix" 11. Run liner to TD on 5"drill pipe&break circulation for upcoming cement job. 12. Pump cement job as per Schlumberger proposal. Top cement placed inside above 10-3/4"liner shoe. 13. Space out the liner hanger to+/- 150' above the 10-3/4"window. 14. Space the packer element onto the 10-3/4"casing body avoiding a casing coupling&keep string in tension when setting the liner hanger. 15. Pressure up to set the liner hanger, slack off weight plus 20 Klbs,continue to pressure up to release the hanger running tool. 16. Bleed off pressure&check floats. 17. Pick up to check the HRD tool released. Pick up until dogs are above liner top. 18. Set down weight at the tool,rotating as necessary to get weight down. 19. After the packer is set,apply drill pipe pressure&pick up slowly to pull the RS pack off. Once the standpipe pressure drops, engage the pump&circulate out any residual cement. 20. Close the annular BOP&pressure test the packer to 1000 psi for 10 minutes. 21. POOH&lay down 5"drill pipe. 22. Pick up baker mule shoe with seal assembly. 23. Run the 7-5/8"tie-back string in hole. 24. After picking up the last joint before stabbing into seals,break circulation at 1-2 BPM. 25. Slowly run in hole watching the pressure increase&hookload indication as seals stab into the tie back extension. Mark entry&stack out depths. 26. Pressure test the 7-5/8"x 10-3/4"annulus with 1000 psi for 10 minutes to prove integrity of the seals. 27. Pull up above the tie back extension. 28. Pick up space out pups,hanger,&landing joint. Ensure casing hanger is not spaced out across annular BOP. 29. Close annular BOP. 30. Pressure test the 7-5/8"liner& 10-3/4"casing to 2000 psi for 10 minutes through the 7-5/8"x 10-3/4"annulus to prove wellbore integrity. 31. Displace LSND mud with brine&flow check for 10 minutes. • S 32. Circulate in inhibitive brine&freeze protect in the 7-5/8"x(10-3/4"& 13-3/8")annulus. Inhibited brine to 7- 5/8"tie-back bottom,and freeze protect to base permafrost. 33. Run in hole with 7-5/8"casing&sting the seals into the sealbore. 34. Land the casing hanger,back out landing joint, install pack off&test. 35. Pressure test the 7-5/8"OA to 2000 psi for 30 minutes to prove final integrity. 36. Lay down any remaining 5"DP. 37. PU 4"DP,6-3/4"bit, and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,LWD Sonic(for CBL)) 38. RIH to above shoe/cement&test intermediate casing to 3500 psi for 30 minutes. 39. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 13.5 ppg&maximum of 16 ppg EMW,record results. 40. Directionally drill 6-3/4"lower lateral hole geo-steering through the Kuparuk A3 sand to TD 16,914'MD/ 6,249' TVD as per directional plan(wp22). Apply MPD pressure while drilling lateral to keep constant bottom hole pressure. 41. Circulate hole clean and POOH. 42. Lay down Production BHA. 43. PU and run 4-1/2", 12.6#liner w/pre-perforated pups. The top of liner will be placed at+/-10,200' MD/6,314' TVD, allowing for @ least 100' of overlap in the 7-5/8"casing. The actual liner hanger setting depth will be determine as drilled&to allow for proper spacing of the multi-lateral equipment. 44. Set liner hanger. Slackoff and set liner top packer. 45. Monitor well for flow for 15 minutes 46. PT liner to 3,000 psi at surface for 30 minutes,chart results. 47. Flow check well for 30 minutes. 48. POOH with liner running tools and lay down. 49. Run whipstock&mill window 50. Mill window until top mill across pace&clean up window. 51. Perform formation integrity test to minimum of 13.5 ppg,maximum of 16 ppg EMW,recording results. 52. POOH with milling BHA. 53. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope) 54. RIH, orient through window,&tag bottom. 55. End 2S-13A PTD&begin 2S-13AL1 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous • • substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Summaries 0 • Attachment 1 — Proposed Well Schematic 2S-13A & AL1 Dual Lat — wr' N,, Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic D142 RKB k• `" Last Edited:SAB-10/3/16 k4 74. 20"Conductor to-117.5' L.,... ..rL,:lr:( r..: G` 16"Surface Hole m ';!;.• ey V 4-W IBTM Tbing Surface Casing 1074 13-3/8"68#L-80 HYD 563 2,847.1'MD/2,559.3'TVD 10-3/4"Planned TOC:5,491.5'(at minimum 12-1/4"X 13-1/2"Intermediate#1 Hole 500'MD above C37) m ,,k.:,,. C 37:6,851.5 MD/4,6595 ND h: j to 7-5/8 x 10-W LinerTop Packer 8,939.5'MD/5,837.5'TVD : :. Growler-AA(Iceberg):7,233.5'MD/4,867.5'TVD -I I Top Cairn:8,2175'MD/54435'TVD cb a Top Bermuda 8,371.5'MD/5529.5'.TVD i 0 z '''' 10%"Whipstock bottom of Window 9,138 MD/5,937.5'TVD " \ HRZ 9219'MD/5975 TVD 70 3l4"INT#1 Liner 5.# +; 10-3/4"45.5#L-80 Hy d521 » --1-1--s#«, 9,3295 MD/6,0295 TVD- '' ' 'l>`. T a P. l-201.41,141-7,0":::'1ti=1 Lateral Entry Module(LEM),Baker,w/seal assembly&ZXP 1'+1;''+*»: r . :4gpacker Bove `` �, ® `�-7/6"httermeLliate#2 Hale` ' o '11.11111111 Top Ku paru k C 9,962 MD/6,262'TVD :rl :Ku9aruk A4:10;-003 MD/6 TVD. - - I a. ;8 1, 26-13PB1/26-13/2S13L1 r` �� 1 1 7-5/8"Whipstock Top of Window 9,999 MD/6,272'TVD .'. S-13L1 A4 TD:17,023'MD/6,215'ND- 7518 Flex Lock Liner Harmer/ZXP 10200 MD/6314'` TVD Kuparuk A3:10 251'MD/6,323 ND F:sR �' ■ sv 0,nw veer k °,-.. . 2�; d o' 25-13 A3 TD.16,914'MD/6249'TVD intermediate Casing 7-5/8"29.7#L-80 Hyd563 Casing 10,316'MD/6,332' 6-3/4"Production Hole TVD(83°) Production liner:4-W linerw/pre-pertorated pups • • Attachment 2 — 2S-13A Directional Plan . 2S-13Awp22 L.R Permit Pack Plan Summary i Kalubik(K-1) 5- U Kalubik 142C(fop C4) -5a) I ./: ` r'' ,I THRS` dY rn In - \1 \iki,‘ILI:Ill\j\liklY 1 I I - I I ....--- 7;,. ./ ;i/ /0 1 I13-3/8"x 16t i I 1 I 1 i I 1 I I i I r 1 ' n I 0 .:•li . i 0 4000 8000 17-5/8"x 9-7/812000 16000 I t fit 20"x 421 Measured Depth 6-3/4"x 4-1/2j I o-.0°-----;20"x42' '... Geodetic Datum: App, Depth Reference: Plan 2S-13:120+39©159.00usft(Doyon142 _ 'Z�3�Q�O 113-3/8"x 16j' Rig: Doyon142 o "0 cp,.epc,- N O O - - h �a 410 3/4"x 13-1/4 I7-5/8"x 9-7/8'I I6-3/4"x 4-1/21 1 \ r/ o X00 I p0 0 . I I I I I I I I I I I Id, r 104 0 I y, I pn t I I 0 1500 3000 4500 6000 750 1'500 S 105118 1P000 C 135Q0 0 9033 - 9210 Horizontal Departure „ - 33° ;45-. �° 30 9210 - 9400 dA 9400 - 9580 d,. ,._ _ a�i0�l l�I�! I�11 2S-14 , 0 � / '''.-*4',.;-1, �.. 9560 - 9760 lc ir� i/�'�:� 40ht1 V, AZIEZI1 1760 - seao t`d 1500 300 r 6ir /l n e 'Ij d 110 ti 60 9940 - 10120 .�, �, 't 10120 - 10300 m ��� t ' 4.� .O4 j X11 t->qr yitilo,,, 10300 - 10580 1�0111������� ( I,fo 1 tr�F ��/4.,,, . 10580 10850 1 aill y 111 t' it/elle. It�P r, t� f 10850 - 11130 U 750Ell 1 "' t Ji41 d,fy ?ii - --jr- a.) 11 a 11130 - 11400 o - 270 I x 9 +1tM1� y:. +°" 7 , 90 .. �, 4 \ '� ,4�p � ;� /� . �N/ //// 11400 - 11880 :'9�SS{9/, /'y, j44.1 s 11666 _ 11950 ° Jjr`1 j` , +� 11950 - 12230 0 CD immin,,..„....iiiln91•19�iiwoio.sn..,.ena�.°...d....'., w..u.� .La.,.,.,n..m.n...,.nll�,.- 3l.1 C; : .,,o ,, 1 ,11,3E J /zesa 12230 12500 4. 9000 10500 12000 13500 15000 16500 ("' � �Fyg".A 12500 - 13050 240 ,+1 1% '' ' '` VVFy 120 jq ...y -eh...4A - 13600 SURVEY PROGRAM � a n `' �'�' Surface Location 4 ` 136001 - 14160 ,��'° 14160 - 14710 Depth From Depth To Survey/Plan Tool .t ‘'c' ��S 94.18 1295.08 2S-13PB1 Srvy#1-SLB_NSG+Battery+SaQ`(TS©QR821) Pad Elevation: 120.00 210 » '� s-sPe, 14710 - 15260 1316.29 2787.04 2S-13PB1 SLB -,-.,....-s4,100.1„ 15260 15810 2879.51 9033.19 2S-13PB1 Srvy#3-SLB MWDi`1SA/®,9((BSA14134,$SC 180 15810 16360 9033.19 9141.50 2S-13Awp22(Plan 2S-13A MWD+IFR-AK-CAZ-SC CASING DETAILS 16360 - 16916 9141.50 9450.00 2S-13Awp22 Plan 2S-13A INC+TREND 9450.00 10316.00 2S-13Awp22 Plan 2S-13A MWD TVD MD Name M 9450.00 10316.00 2S-13Awp22 Plan 25-13A MWD+IFR-AK-CAZ-SC 5939.07 9141.50 10 3/4"x 13-1/2 Magnetic Model: BGGM2016 T 10316.00 11816.00 2S-13Awp22 Plan 2S-13A MWD 6332.00 10315.90 7-5/8"x 9-7/8" Magnetic Model Date: 20-Oct-18 - 10316.00 16913.49 2S-13Awp22(Plan 2S-13A) MWD+IFR-AK-CAZ-SC 6249.00 16913.49 6-3/4"x 4-1/2" Magnetic Declination: 17.77° To convert a Magnetic Direction to a True Direction,Add 17.77°East SECTION DETAILS Sec MD Inc Azi TVD ON/-S +E/-W Dleg TFace VSect Target Annotation 1 9033.19 59.42 323.94 5885.32 -1063.80 -5478.30 0.00 0.00 -2873.33 KOP:3.5°/100'DLS,70.23°TF,for 86.11' 2 9119.30 80.48 327.20 5928.45 -1002.33 -5520.42 3.50 70.23 -2829.98 Start 9.65°/100'DLS,-30°TF,for 22.2' 3 9141.50 62.34 325.99 5939.07 -986.06 -5531.16 9.65 -30.00 -2818.36 Hold for 28.5' -5974.8 4 9170.00 62.34 325.99 5952.30 -965.13 -5545.28 0.00 0.00 -2803.52 Start 3°/100'DLS,-30°TF,for 60' 5 9230.00 63.90 324.99 5979.43 -921.04 -5575.60 3.00 -30.00 -2772.46 Adjust TF to 171.81°,for 77.72' 6 9307.72 61.60 325.37 6015.01 -864.32 -5615.05 3.00 171.81 -2732.66 Hold for 18.85' 7 9326.57 61.60 325.37 6023.98 -850.68 -5624.47 0.00 0.00 -2723.06 Start 3.5°/100'DLS,58.18°TF,for 989.34' THRZ 8 10315.90 82.65 354.50 6332.00 22.41 -5928.08 3.50 58.18 -2006.46 2S-13A Tgt 0 7-5/8 081816 PB Hold for 20' 9 10335.90 82.65 354.50 6334.56 42.16 -5929.98 0.00 0.00-1988.56 Start 3°/100'DLS,64.95°TF,for 732.61' 10 10943.87 91.90 13.71 6383.71 644.38 -5888.39 3.50 64.96 -1407.76 11 12635.65 91.90 13.71 6307.68 2287.06 -5485.72 0.00 0.00 272.90 12 12709.60 90.70 12.30 6306.00 2359.09 -5469.09 2.50 -130.26 346.28 2S-13A Tgt 1 Line up pre-truncation JH 092916 -6089.8 13 14095.60 90.70 12.30 6289.00 3713.19 -5173.93 0.00 0.00 1719.67 2S-13A Tgt 2 Dive prior to fault JH 092916 14 14272.43 86.01 16.33 6294.07 3884.38 -5130.26 3.50 139.35 1895.47 15 14280.22 86.01 16.33 6294.62 3891.84 -5128.07 0.00 0.00 1903.23 U Kalubik 16 14406.15 90.00 18.21 6299.00 4011.99 -5090.72 3.50 25.16 2028.91 2S-13ATgt 3 Fault Location JH 092916 17 14412.77 89.88 18.26 6299.01 4018.27 -5088.65 2.00 155.34 2035.52 18 14928.82 89.88 18.26 6300.09 4508.33 -4926.94 0.00 0.00 2551.34 19 15018.83 91.51 17.51 8299.00 4593.79 -4899.36 2.00 -24.66 2641.07 2S-13ATgt 4 In Zone after fault JH 092918 -6171.8 20 16913.49 91.51 17.51 8249.00 6400.20 -4329.38 0.00 0.00 4533.48 2S-13A Tgt 5 Toe JH 092916 Kalubik(K-1) Fails AC with 2S-13, 2S-13PB1, & -mo C(Top C4) 2S-13L1. A4 -6322.8 A3 9-By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured 8's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well 'repared by: Checked by: Accepted by: Approved by: randon Tempi Vincent Osara Erik Sterk • • 0 5 45 . Q O. ,_ ,_ m J �� • S Q v N< NN o Nordling (3000 usft/in) M N _ _ ^' M Y 0) 3 N N NM — J _ O Y OJ � _ J_ JN, O CO _ N _ . CD N O J Cl W — 3 0 - - i t th - M (Ii--) N - - O th c — O — 2 - N — N- — O th O M N �2 --'''-'.... 28 o ?� • _ O • _ m cc)"a. NO N d J _... J N cl — _ M CO ON sn - M N N fit; t* N NiN N 7 7 O— ,..._ IC o O - '0,',1" 5` O v N v H— M I 00 N O CD i: d Q N _ t- — S N LO — m (!J M _ M N _ N — N — 00O CO MO O _ — J CO J — N J N N N - (.O O - - ON _ O Q M — (`7 CO N p — N M N J _ �_ N Q - do coa ti C5 O N• M 0-- Cl. O 1 J M O M, N O J r (XI'- N C7 V N C1 J M J- N J N to N _ i JCO 0 `� N M — CO M V co ✓ O M O M / •." N N J N _ N -� _ 0o 1/7 Lc) \_a ir, ,,,,, / o , 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 1 I l 1 I t l , , I , i , , , , i I I I I ✓ (u!J;sn 000£) 6u!4poN r ri r • a) 5 cz 0 _o 0 rn 0 N , ■. o _O o o 0 q C 3QN d o ai o O CIS C� 6 N o i —O , O i co I , , , Q p c O 4L \, #, ___ _.......— toi \'‘, \‘, 111, IIN �� o, 0 _oco Oca o ` \` o O p W CO 0 0/ - 4° Q ° a cpo s: , (0 0 000 ``��- M N o 0'6) 0 o / I -o co IN ,, c.i,I N00. (v / I , o m O l , -O N tnN rn a C/1) 8Mci. co o r0 1 N N N © 0 _0 in 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 rn co (d4sn 000£) (+)upoN/(-)uin&S co rn • a) -;Tio (i) U co V • I ..I. I, • m N O O co = r o OF- = 2S-13Awp22 en cs Q 45 , CDas • 1r ,,• 4 N Nco ' c N O x O o 15) CO F- _ M = t. N 000 c� — r -' 0 0)♦ + o V 0 o N O w U J O co ias (0 112 LL 0 5000 .E M L.06 eL o 4- 1E 0 Q D • O = O O co Q ON cp O NO 4000 O O ca \to O N O —, a1co (13 C N N O y=- 3000 Om - C!) o 0 o o CO U N- O = -'q, OO CO 1 v- M� Q OD N N CO o 1.11,2-2-0000 N N oo < O CI x `'Do 0 �-, 0 o o Q x �� M 'n06 1-000 M co 0 0o N ss O O 0 , bo N °°° 000 o �' cp' o x O N O Zo T — ,� 0 o O o O o x 0 0 0 0 0 0 ' o (ui�}.sn 000L) LadeQ Ieai A anal 0 0 r Plan Report i • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-13 Plan: 2S-13A Plan: 2S-13Awp22 Report 03 October, 2016 i • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well 2S-13 Well Position +N/-S 0.00 usft Northing: Latitude: +EI-W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore Plan:2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) 6,44,.-(nT) BGGM2016 10/20/2016 17.77 80.84 57,532 Design 2S-13Awp22 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,033.19 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 20.00 Survey Tool Program Date 10/3/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 94.18 1,295.08 2S-13PB1 Srvy#1-SLB_NSG+Battery+S GYD-GC-SS Gyrodata gyro single shots 1,316.29 2,787.04 2S-13PB1 Srvy#2-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,879.51 9,033.19 2S-13PB1 Srvy#3-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,033.19 9,141.50 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,141.50 9,450.00 2S-13Awp22(Plan:2S-13A) INC+TREND Inclinometer+known azi trend 9,450.00 10,316.00 2S-13Awp22(Plan:2S-13A) MWD MWD-Standard 9,450.00 10,316.00 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,316.00 11,816.00 2S-13Awp22(Plan:2S-13A) MWD MWD-Standard 10,316.00 16,913.49 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 9,033.19 59.42 323.94 5,885.32 5,726.32 0.00 0.00 14.77 KOP:3.5°1100'DLS,70.23°TF,for 86.11' 9,100.00 60.24 326.48 5,918.90 5,759.90 3.50 70.23 14.07 9,119.30 60.48 327.20 5,928.45 5,769.45 3.50 68.96 13.83 Start 9.65°/100'DLS,-30°TF,for 22.2' 10/3/2016 2:21.45PM Page 2 COMPASS 5000.1 Build 74 • S Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 9,141.50 62.34 325.99 5,939.07 5,780.07 9.65 -30.00 14.32 Hold for 28.5'-10 3/4"x 13-1/2 9,170.00 62.34 325.99 5,952.30 5,793.30 0.00 0.00 15.18 Start 3°/100'DLS,-30°TF,for 60' 9,200.00 63.12 325.49 5,966.05 5,807.05 3.00 -30.00 21.20 9,219.53 63.63 325.16 5,974.80 5,815.80 3.00 -29.77 29.87 THRZ 9,230.00 63.90 324.99 5,979.43 5,820.43 3.00 -29.62 29.87 Adjust TF to 171.81°,for 77.72' 9,300.00 61.82 325.33 6,011.35 5,852.35 3.00 171.81 52.51 9,307.72 61.60 325.37 6,015.01 5,856.01 3.00 171.66 55.09 Hold for 18.85' 9,326.57 61.60 325.37 6,023.98 5,864.98 0.00 0.00 61.39 Start 3.5°/100'DLS,58.18°TF,for 989.34' 9,400.00 62.97 327.82 6,058.13 5,899.13 3.50 58.18 86.21 9,471.37 64.35 330.14 6,089.80 5,930.80 3.50 57.04 103.07 U Kalubik 9,500.00 64.91 331.06 6,102.07 5,943.07 3.50 56.01 103.07 9,600.00 66.92 334.20 6,142.88 5,983.88 3.50 55.62 102.38 9,676.24 68.50 336.53 6,171.80 6,012.80 3.50 54.34 101.44 Kalubik(K-1) 9,700.00 68.99 337.25 6,180.41 6,021.41 3.50 53.45 101.44 9,800.00 71.11 340.21 6,214.53 6,055.53 3.50 53.19 100.28 9,900.00 73.28 343.09 6,245.11 6,086.11 3.50 52.18 98.92 9,960.35 74.61 344.80 6,261.80 6,102.80 3.50 51.30 97.38 Kup C(Top C4) 10,000.00 75.49 345.91 6,272.03 6,113.03 3.50 50.83 97.38 10,003.08 75.56 346.00 6,272.80 6,113.80 3.50 50.54 95.67 A4 10,100.00 77.73 348.68 6,295.19 6,136.19 3.50 50.52 95.67 10,200.00 80.00 351.40 6,314.51 6,155.51 3.50 49.90 93.80 10,250.60 81.15 352.76 6,322.80 6,163.80 3.50 49.38 91.78 A3 10,300.00 82.28 354.08 6,329.92 6,170.92 3.50 49.15 91.78 10,315.90 82.65 354.50 6,332.00 6,173.00 3.50 48.96 91.45 Hold for 20'-7-5/8"x 9-7/8" 10,335.90 82.65 354.50 6,334.56 6,175.56 0.00 48.91 90.72 Start 3°/100'DLS,64.95°TF,for 732.61' 10,400.00 83.60 356.55 6,342.23 6,183.23 3.50 64.96 88.93 10,500.00 85.11 359.72 6,352.07 6,193.07 3.50 64.72 85.95 10,600.00 86.63 2.88 6,359.28 6,200.28 3.50 64.40 82.76 10,700.00 88.16 6.03 6,363.83 6,204.83 3.50 64.18 79.36 10,800.00 89.69 9.18 6,365.71 6,206.71 3.50 64.03 75.78 10,900.00 91.23 12.33 6,364.91 6,205.91 3.50 63.97 72.02 10,943.87 91.90 13.71 6,363.71 6,204.71 3.50 64.00 70.31 11,000.00 91.90 13.71 6,361.86 6,202.86 0.00 0.00 70.38 10/3/2016 2:21:45PM Page 3 COMPASS 5000.1 Build 74 0 • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 11,068.51 91.90 13.71 6,359.59 6,200.59 0.00 0.00 70.49 Hold for 1516.86' 11,100.00 91.90 13.71 6,358.54 6,199.54 0.00 0.00 70.49 11,200.00 91.90 13.71 6,355.23 6,196.23 0.00 0.00 70.63 11,300.00 91.90 13.71 6,351.92 6,192.92 0.00 0.00 70.81 11,400.00 91.90 13.71 6,348.61 6,189.61 0.00 0.00 71.01 11,500.00 91.90 13.71 6,345.29 6,186.29 0.00 0.00 71.24 11,600.00 91.90 13.71 6,341.98 6,182.98 0.00 0.00 71.50 11,700.00 91.90 13.71 6,338.67 6,179.67 0.00 0.00 71.79 11,800.00 91.90 13.71 6,335.36 6,176.36 0.00 0.00 72.11 11,900.00 91.90 13.71 6,332.05 6,173.05 0.00 0.00 70.31 12,000.00 91.90 13.71 6,328.73 6,169.73 0.00 0.00 70.35 12,100.00 91.90 13.71 6,325.42 6,166.42 0.00 0.00 70.40 12,200.00 91.90 13.71 6,322.11 6,163.11 0.00 0.00 70.46 12,300.00 91.90 13.71 6,318.80 6,159.80 0.00 0.00 70.51 12,400.00 91.90 13.71 6,315.48 6,156.48 0.00 0.00 70.58 12,500.00 91.90 13.71 6,312.17 6,153.17 0.00 0.00 70.65 12,585.37 91.90 13.71 6,309.34 6,150.34 0.00 0.00 70.72 Start 2°/100'DLS,-126.47°TF,for 126.67' 12,600.00 91.90 13.71 6,308.86 6,149.86 0.00 0.00 70.72 12,635.65 91.90 13.71 6,307.68 6,148.68 0.00 0.00 70.74 12,700.00 90.86 12.48 6,306.13 6,147.13 2.50 -130.26 72.33 12,709.60 90.70 12.30 6,306.00 6,147.00 2.50 -130.29 72.56 12,712.03 90.70 12.30 6,305.97 6,146.97 0.00 0.00 72.59 Hold for 1386' 12,800.00 90.70 12.30 6,304.89 6,145.89 0.00 0.00 72.59 12,900.00 90.70 12.30 6,303.66 6,144.66 0.00 0.00 72.67 13,000.00 90.70 12.30 6,302.44 6,143.44 0.00 0.00 72.76 13,100.00 90.70 12.30 6,301.21 6,142.21 0.00 0.00 72.85 13,200.00 90.70 12.30 6,299.99 6,140.99 0.00 0.00 72.95 13,300.00 90.70 12.30 6,298.76 6,139.76 0.00 0.00 73.05 13,400.00 90.70 12.30 6,297.53 6,138.53 0.00 0.00 73.15 13,500.00 90.70 12.30 6,296.31 6,137.31 0.00 0.00 73.26 13,600.00 90.70 12.30 6,295.08 6,136.08 0.00 0.00 73.38 13,700.00 90.70 12.30 6,293.85 6,134.85 0.00 0.00 73.49 13,800.00 90.70 12.30 6,292.63 6,133.63 0.00 0.00 73.62 13,900.00 90.70 12.30 6,291.40 6,132.40 0.00 0.00 73.74 14,000.00 90.70 12.30 6,290.17 6,131.17 0.00 0.00 73.88 14,095.60 90.70 12.30 6,289.00 6,130.00 0.00 0.00 74.00 14,098.03 90.64 12.35 6,288.97 6,129.97 3.50 139.35 73.88 Start 3.5°/100'DLS,139.35°TF,for 176.83' 14,100.00 90.59 12.40 6,288.95 6,129.95 3.50 139.35 73.88 14,200.00 87.93 14.68 6,290.24 6,131.24 3.50 139.35 70.94 14,272.43 86.01 16.33 6,294.07 6,135.07 3.50 139.32 68.75 10/3/2016 2:21:45PM Page 4 COMPASS 5000.1 Build 74 • 0 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) ,`;;(usft) (usft) (°1100usft) (°) (usft) 14,274.86 86.01 16.33 6,294.24 6,135.24 0.00 0.00 68.75 Hold for 7.79' 14,280.22 86.01 16.33 6,294.62 6,135.62 0.00 0.00 68.75 14,282.65 86.09 16.37 6,294.78 6,135.78 3.50 25.16 68.39 Start 3.5°/100'DLS,25.16°TF,for 125.93' 14,300.00 86.64 16.63 6,295.88 6,136.88 3.50 25.16 68.39 14,400.00 89.80 18.11 6,298.99 6,139.99 3.50 25.14 66.55 14,406.15 90.00 18.21 6,299.00 6,140.00 3.50 25.10 66.44 14,408.58 89.96 18.23 6,299.00 6,140.00 2.00 155.34 66.36 Start 2°/100'DLS,155.34°TF,for 6.62' 14,412.77 89.88 18.26 6,299.01 6,140.01 2.00 155.34 66.36 14,415.20 89.88 18.26 6,299.01 6,140.01 0.00 0.00 66.41 Hold for 516.05' 14,500.00 89.88 18.26 6,299.19 6,140.19 0.00 0.00 66.41 14,600.00 89.88 18.26 6,299.40 6,140.40 0.00 0.00 66.56 14,700.00 89.88 18.26 6,299.61 6,140.61 0.00 0.00 66.71 14,800.00 89.88 18.26 6,299.82 6,140.82 0.00 0.00 66.87 14,900.00 89.88 18.26 6,300.03 6,141.03 0.00 0.00 67.04 14,928.82 89.88 18.26 6,300.09 6,141.09 0.00 0.00 67.09 14,931.25 89.92 18.24 6,300.09 6,141.09 2.00 -24.66 67.99 Start 2°/100'DLS,-24.66°TF,for 89.81' 15,000.00 91.17 17.67 6,299.44 6,140.44 2.00 -24.66 67.99 15,018.63 91.51 17.51 6,299.00 6,140.00 2.00 -24.66 68.23 15,021.06 91.51 17.51 6,298.94 6,139.94 0.00 0.00 68.36 Hold for 1894.86' 15,100.00 91.51 17.51 6,296.85 6,137.85 0.00 0.00 68.36 15,200.00 91.51 17.51 6,294.21 6,135.21 0.00 0.00 68.54 15,300.00 91.51 17.51 6,291.58 6,132.58 0.00 0.00 68.72 15,400.00 91.51 17.51 6,288.94 6,129.94 0.00 0.00 68.90 15,500.00 91.51 17.51 6,286.30 6,127.30 0.00 0.00 69.09 15,600.00 91.51 17.51 6,283.66 6,124.66 0.00 0.00 69.29 15,700.00 91.51 17.51 6,281.02 6,122.02 0.00 0.00 69.49 15,800.00 91.51 17.51 6,278.38 6,119.38 0.00 0.00 69.69 15,900.00 91.51 17.51 6,275.74 6,116.74 0.00 0.00 69.90 16,000.00 91.51 17.51 6,273.10 6,114.10 0.00 0.00 70.11 16,100.00 91.51 17.51 6,270.47 6,111.47 0.00 0.00 70.32 16,200.00 91.51 17.51 6,267.83 6,108.83 0.00 0.00 70.54 16,300.00 91.51 17.51 6,265.19 6,106.19 0.00 0.00 70.77 16,400.00 91.51 17.51 6,262.55 6,103.55 0.00 0.00 70.99 16,500.00 91.51 17.51 6,259.91 6,100.91 0.00 0.00 71.23 16,600.00 91.51 17.51 6,257.27 6,098.27 0.00 0.00 71.46 16,700.00 91.51 17.51 6,254.63 6,095.63 0.00 0.00 71.70 16,800.00 91.51 17.51 6,251.99 6,092.99 0.00 0.00 71.94 16,900.00 91.51 17.51 6,249.36 6,090.36 0.00 0.00 72.19 16,913.49 91.51 17.51 6,249.00 6,090.00 0.00 0.00 72.22 10/3/2016 2:21:45PM Page 5 COMPASS 5000.1 Build 74 • 0 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 25-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,141.50 5,939.07 10 3/4"x 13-1/2 10-3/4 13-1/2 16,913.49 6,249.00 6-3/4"x 4-1/2" 4-1/2 6-3/4 10,315.90 6,332.00 7-5/8"x 9-7/8" 7-5/8 9-7/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 9,471.37 6,089.80 U Kalubik 0.00 9,219.53 5,974.80 THRZ 0.00 10,250.60 6,322.80 A3 0.00 10,003.08 6,272.80 A4 0.00 9,676.24 6,171.80 Kalubik(K-1) 0.00 9,960.35 6,261.80 Kup C(Top C4) 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment " 9,033.19 5,885.32 -1,063.80 -5,478.30 KOP:3.57100'DLS,70.23°TF,for 86.11' 9,119.30 5,928.45 -1,002.33 -5,520.42 Start 9.65°/100'DLS,-30°TF,for 22.2' 9,141.50 5,939.07 -986.06 -5,531.16 Hold for 28.5' 9,170.00 5,952.30 -965.13 -5,545.28 Start 3°/100'DLS,-30°TF,for 60' 9,230.00 5,979.43 -921.04 -5,575.60 Adjust TF to 171.81°,for 77.72' 9,307.72 6,015.01 -864.32 -5,615.05 Hold for 18.85' 9,326.57 6,023.98 -850.68 -5,624.47 Start 3.50/100'DLS,58.18°TF,for 989.34' 10,315.90 6,332.00 22.41 -5,928.08 Hold for 20' 10,335.90 6,334.56 42.16 -5,929.98 Start 3°/100'DLS,64.95°TF,for 732.61' 11,068.51 6,359.59 765.38 -5,856.87 Hold for 1516.86' 12,585.37 6,309.34 2,238.23 -5,497.63 Start 2°/100'DLS,-126.47°TF,for 126.67' 12,712.03 6,305.97 2,361.47 -5,468.57 Hold for 1386' 14,098.03 6,288.97 3,715.57 -5,173.41 Start 3.5°/100'DLS,139.35°TF,for 176.83' 14,274.86 6,294.24 3,886.71 -5,129.58 Hold for 7.79' 14,282.65 6,294.78 3,894.17 -5,127.39 Start 3.5°/100'DLS,25.16°TF,for 125.93' 14,408.58 6,299.00 4,014.30 -5,089.96 Start 2°/100'DLS,155.34°TF,for 6.62' 14,415.20 6,299.01 4,020.58 -5,087.88 Hold for 516.05' 14,931.25 6,300.09 4,510.64 -4,926.18 Start 2°/100'DLS,-24.66°TF,for 89.81' 15,021.06 6,298.94 4,596.11 -4,898.63 Hold for 1894.86' 16,915.92 TD:16915.92'MD,6249'TVD Checked By: Approved By: Date: 10/3/2016 2:21.45PM Page 6 COMPASS 5000.1 Build 74 AC Report 0 • N fai '0 '3 .E c N_ I C O N ' E C v C N a C to ma m N O U a O owl'\ y W O CU ` 0 O N !%7 O 3 2 o i L Q a + (I) r m o /V1) o 0 •Y �+ Z ch E (N Lill IS N _ G N C w O R Q 7 Q w! o a y 3 cV T o a N N O Q (6 '� ^��^++ = .. Q a Q V+ W = . U 3 cE C d CO O w L 7 N U Q O G iii C N p�p�� ' C in C V 3 R d N CL ■ .4_, O co {C Ol a- - Q V a M C 0 ■IIIIINI �, CO N U W CC 0 > N 0 N N N Q -a C1) Ce (NI ( NQ !Q 0 L. C0N: 7 O °i r m Me o 6 .a O .. a 2 ,, 2UNO N /\ C Z w _o LN Q CtS '. cD v47,c m o ci o (13 (13M . 05 W) " fl- c c• v Cvuas co u V 1Na N 0 < ( �' Tu- = mmo mm 0 r o in in 0 > coo 0 2. r .::_o..;-:-.77 's-:iiitLii4,4 t-i,i ii 0 cr) ., o CC o N N " F>. N_ N ix fx T. R O O - O O 4'en 2 2 `�� i i i rc,. N 0)����k (" N N N N .tea"' N a a . a d C a a m E IIIHF co coE ° uv) u) cnU) d 0 0 0 0 0 Y Y Y Y Y ill HN M IIII o M U) Q�/ Q Q 0 <V' (O U) C2 ci K 2 Z KC o N- (fi U L.,.. ,..,_ ,..,.. W LL LL al cp U LL 0- U 0 o 0 1111 ° a o 0 0 0 LO Lf) COt N N 1111 ,i NN G V (O CO 0 N Q 7 CO CO CO o V m rn Cr (n C N N NH rn C r r N. .2 M M: 1111 N (A C1 ` V V rn of = v iii U) Lo O O O co LO N Ts N N CO . 2 N N LI O C eo tm O a:'�.' 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M W O V' V' M M L .- co R a- 4, — M 0 N co 'V' V d LL LL oo co N N O (O C. 01 J J E Y _ w E Et 2 2 = CO N N CO CO u) u) N N Q Q V V' d co O a O N Z .,- r N N M M r r O a Y 0 I� cn co a N T co m N N m m 05 0) N N N O W N 0 C 2 N N N CO M M CC M d N N V V •y S O C �- •-- C C c' v/ Z .,7, 01 N N N n n n n UUUU6 @ UU 02 ct, E = O_ CV O C y C ;?, Z O. a N N CO CO CO CO CO CO M CO V V (cbcb E O .0 U y IC • O O U) U) O) U) U) U) U) U) U) CO U) U) (") j y C C m U Y N N N N N N N N N N N N *4( O (0 (6 I-- Q' U) co 0 • « \ / \ ala.3 q a)f Csl < E ' -Si 2 ) a C \ } k I c \ ? CO - Q - q $ 2 G s E § CI a)- § R I ; \ j q a) E) \ \ \ 4— uul j \ a c o ' { 2 T. § \ co / / \ 66 _ - / )C - o k °§ @ . E0 \ / ) E _ + v C \®2. C _ ^/ \ \ \Q \j Ladder View • 14:25, October 03 2016 2Lad er View S-13Awp22 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. m 300 N (_ o _ I u) 92 J AIMIhh. AMIIIIIININftim....— < X150 U III111111 a, ® ' o kird11111111Weili 0 A / l� � te, l r ` • ®_ moola hif _ H_.__ l 9000 10500 12000 13500 15000 16500 Displayed interval could be less than entire well:Measured Depth9033.19 To 16914.17 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 94.18 1295.08 25-13PB1 Srvy#1 -SLB_NSG+Bat +60g4$8-13PB1) 5939.03141.50 10 3/4"x 13-1/2 1316.29 2787.04 2S-13PB1 Srvy#2-SLB_MWD+GMlrD9B 3lR'B(3AZ-SC 6332.'tffB15.90 7-5/8"x 9-7/8" 2879.51 9033.19 2S-13PB1 Srvy#3-SLB_MWD+GMW9(�2BR1. 1R>B3)1Z-SC 6249.11913.49 6-3/4"x 4-1/2" 9033.19 9141.50 2S-13Awp22 (Plan: 2S-13A) MWD+IFR-AK-CAZ-SC 9141.50 9450.00 2S-13Awp22 (Plan: 2S-13A) INC+TREND 9450.0010316.00 2S-13Awp22 (Plan: 2S-13A) MWD 9450.0010316.00 2S-13Awp22 (Plan: 2S-13A) MWD+IFR-AK-CAZ-SC 10316 0011816 00 2S-13Awn22 (Plan. 2S-13A1 MWD N N a 3 mj a i e N N N 60 mossin,/immAINIMINIMIFT — -..mliq C O \ Ilk __. I _. U O c a) U r , 0 i f i I I f I i l ' 1 I ' I 9000 9500 10000 10500 11000 11500 12000 12500 Partial Measured Depth TC View MD 9,;'111,r4 n 1 TVD +N/-S +FJ-W Dleg TFace VSe t U 9U33 90 3.79 59.4 .94 5885.32 -1063.80 -5478.30 0.00 0.00 -2873.3 2S-13Awp22 91 9.30 60.4 .20 5928.45 1002.33 5520.42 3.50 70.23 2829.98 9033 9210 91 1.50 62.34 326.99 5939.07 -986.06 5531.16 9.65 -30.00 -2818.36 9033.00 To 16914.1 91 0.00 62.34 325.99 5952.30 965.13 5545.28 0.00 0.00 2803.52 9210 9400 92 0.00 63.90 324.99 5979.43 -921.04 -5575.60 3.00 -30.00 -2772.46 7 93 7.72 61.60 325.37 6015.01 -864.32 -5615.05 3.00 171.81 -2732.66 " 6.57 61.60 325.37 6023.98 -850.68 -5824.47 0.00 0.00 -2723.06 9400 9580 5.90 82.65 354.50 6332.00 22.41 -5928.08 3.50 58.18 -2006.46 2S13A Tgt 0 7-5/8 081816 PB 16:08,September 30 2016 5.90 82.65 354.50 :36 71 42.16 5929.98 0.00 0.00 1966.66 9580 9760 3.87 91.90 13.71 6363.71 644.36 -5886.39 3.50 64.96 -1407.76 SURVEY PROGRAM sss st so 7 3.71 6307.85 2zazos -5485.72 0.00 0.00 27zs° 9760 9940 9.60 90.70 12.30 6306.00 2359.09 -5469.09 2.50 -130.26 346.28 2S73ATgt 1 Line up pre-truncation JH 092916 CPin From owls To 0Srvey�plan 61 T6u� 5.60 90.70 12.30 6289.00 3713.19 -5173.93 0.00 0.00 1779.67 2S13AT t2 Dive nor to fault JH 092916 96.16 1]95.03 23-103101„v.- , au-6La_Nw,,, *,y6.om(03 aa1]Pail 9 p 28]9.61 9033.9 2,9-1]arafea P01Oss m.NLa_MW 8a n40a 130 2.43 86.01 16.33 6294.07 3884.38 -5130.26 3.50 139.35 1895.47 9940 10120 9033.19 9161.60 25.13Avg221Pbn:25-13A)M1TNWIFR-AK-GAZSG 0.22 86.01 16.33 6294.62 3891.84 -5128.07 0.00 0.00 1903.23 9161.60 9460.00 25-03Axp221Plan:ffi-9A1 INC+TREND 6.15 90.00 18.21 6299.00 4011.99 -5090.72 3.50 25.18 2028.91 2S-13A Tgt 3 Fault Location JH 092916 10120 10300 9660.00 10]16.00 26-13Awp221P1an:25.13A1 MND 2.77 89.88 18.26 8299.01 4018.27 -5088.65 2.00 155.34 2035.52 9650.00 10316.00 2S-13Awp221P1an:26-1sA1 MW9«IFR-AK-GAZSC 10316.00 16913.49 zsi30smaO2j • • >N c 0 cn a� 0 a • • Northing (2500 usft/in) 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 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 - r- - _ o - U) - N CC; - - O - Q - - rn - - o _ — U) — _ N - O — N J (13 O NCl) ,� N — m _ _ — ,_ 1.... • ) —a 7 7 N - 0 In - `...�7 - Ln N � % — 0 - eiii, rn C oy W— N d') --W 71 ,,,,,,.,_,,,,4 ---------- ., \ - RS N CO Ch— cv co c� N N Oa _ r N _ co _ N - - -__.. 1 1 1 1 1 1 1 1 1 1 I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 csi (u!Risn 0092) 6u!UioN AC Flipbook • 000 0 0 0 0 0 0 0 0 Om O0 0 0 0 0 000 rI1 ni if) qD Oc0 k.0 rn .,_"1 71- rn mmo N d' o 0 0 0 N N d' d Ln o [ 5 s i O M O O O O O O O O O O O O O O O O O O O O O O rr r' O 00 \.0 d" N f, M O 00 LO 00 in Mo in O vO r' r k.0 0d- in N. 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S, ®'ply,"j, 't 1 '' ' zz-'1\\II re#,40tkr-',.e.„. 0 f= \\A , • 4 s 'o'P, V, I rr01,00A4 14 11tv Ob /rrl / # QRZ S�I 1,444101 gQ� j�I 'R65 i c �• rn d-ON O o 0 N 1- N O o L N O cs �"� v M pr 0 rn rn rn N- N. 0 0 0 o m m 10 Ro 0. r' Q N 61 Q1 Q1 Q1 (1:;:‘, M V1 to ^ M M M M N N N L/1 �.(1 to r Q Q M IP,-, t.n T- M L4 d" d' M 00 00 N N N N N52 ii,c N 00 M M (r.:, M M M M M M r p 01 O O O O N I� O O n V1 O O M N V1 t\ N Cr 01 • M '- M I.n• O• O n 61 61 00 R. '0 '0 d' r• N. co• '0 [• r M a• O O• ^ r.(1 t!1 M V1 01 V1 N O 0 N 00 CO M 01 01 01 61 0, 01 01 O p p N N dO"d ' d- d' d' .1- v1 s.0 Errors Report i • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-13 Plan: 2S-13A Plan: 2S-13Awp22 Report - Errors 30 September, 2016 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKE D M P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well 2S-13 Well Position +N/-S 0.00 usft Northing: Latitude: +E/-W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 120.00 usft Wellbore Plan:2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M 2016 10/20/2016 17.77 80.84 57,532 Design 2S-13Awp22 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,033.19 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 20.00 Survey Tool Program Date 9/30/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 94.18 1,295.08 25-13PB1 Srvy#1-SLB_NSG+Battery+S GYD-GC-SS Gyrodata gyro single shots 1,316.29 2,787.04 25-13PB1 Srvy#2-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,879.51 9,033.19 2S-13PB1 Srvy#3-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,033.19 9,141.50 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZ SCC 9,141.50 9,450.00 2S-13Awp22(Plan:2S-13A) INC+TREND Inclinometer+known azi trend 9,450.00 10,316.00 2S-13Awp22(Plan:2S-13A) MWD MWD-Standard 9,450.00 10,316.00 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,316.00 11,816.00 2S-13Awp22(Plan:2S-13A) MWD MWD-Standard 10,316.00 16,913.49 2S-13Awp22(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 9,033.19 20.91 59.42 82.58 5,726.32 8.63 14.77 15.86 KOP:3.5°/100'DLS,70.23°TF,for 86.11' 9,100.00 21.68 60.24 82.99 5,759.90 8.65 14.07 15.85 9,119.30 21.86 60.48 83.06 5,769.45 8.65 13.83 15.82 Start 9.65°/100'DLS,-30°TF,for 22.2' 9/30/2016 4:31:05PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger 4111 Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 9,141.50 22.02 62.34 83.15 5,780.07 8.65 14.32 15.20 Hold for 28.5'-10 3/4"x 13-1/2 9,170.00 22.02 62.34 83.98 5,793.30 8.64 15.18 15.20 Start 3°/100'DLS,-30°TF,for 60' 9,200.00 22.08 63.12 92.03 5,807.05 8.67 21.20 14.95 9,219.53 22.13 63.63 111.59 5,815.80 8.70 29.87 14.72 THRZ 9,230.00 22.13 63.90 111.59 5,820.43 8.70 29.87 14.72 Adjust TF to 171.81°,for 77.72' 9,300.00 22.05 61.82 137.13 5,852.35 8.78 52.51 15.51 9,307.72 21.75 61.60 138.15 5,856.01 8.79 55.09 15.48 Hold for 18.85' 9,326.57 21.75 61.60 139.80 5,864.98 8.83 61.39 15.50 Start 3.5°/100'DLS,58.18°TF,for 989.34' 9,400.00 22.68 62.97 143.18 5,899.13 9.04 86.21 15.47 9,471.37 24.81 64.35 144.33 5,930.80 9.20 103.07 15.57 U Kalubik 9,500.00 24.81 64.91 144.33 5,943.07 9.20 103.07 15.57 9,600.00 27.79 66.92 144.24 5,983.88 9.21 102.38 15.68 9,676.24 31.33 68.50 144.17 6,012.80 9.23 101.44 15.78 Kalubik(K-1) 9,700.00 31.33 68.99 144.17 6,021.41 9.23 101.44 15.78 9,800.00 35.22 71.11 144.10 6,055.53 9.27 100.28 15.74 9,900.00 39.31 73.28 144.05 6,086.11 9.31 98.92 15.52 9,960.35 43.50 74.61 144.01 6,102.80 9.37 97.38 15.08 Kup C(Top C4) 10,000.00 43.50 75.49 144.01 6,113.03 9.37 97.38 15.08 10,003.08 47.72 75.56 143.99 6,113.80 9.44 95.67 14.41 A4 10,100.00 47.72 77.73 143.99 6,136.19 9.44 95.67 14.41 10,200.00 51.89 80.00 143.98 6,155.51 9.53 93.80 13.54 10,250.60 55.98 81.15 144.00 6,163.80 9.62 91.78 12.53 A3 10,300.00 55.98 82.28 144.00 6,170.92 9.62 91.78 12.53 10,315.90 56.62 82.65 144.00 6,173.00 9.64 91.45 12.36 Hold for 20'-7-5/8"x 9-7/8" 10,335.90 56.14 82.65 144.20 6,175.56 9.29 90.72 12.05 Start 3°/100'DLS,64.95°TF,for 732.61' 10,400.00 59.04 83.60 144.17 6,183.23 9.29 88.93 11.65 10,500.00 63.48 85.11 144.15 6,193.07 9.31 85.95 10.96 10,600.00 67.76 86.63 144.14 6,200.28 9.34 82.76 10.28 10,700.00 71.87 88.16 144.15 6,204.83 9.38 79.36 9.73 10,800.00 75.78 89.69 144.18 6,206.71 9.44 75.78 9.46 10,900.00 79.46 91.23 144.23 6,205.91 9.52 72.02 9.63 10,943.87 80.99 91.90 144.26 6,204.71 9.56 70.31 9.87 11,000.00 80.99 91.90 144.30 6,202.86 9.61 70.38 9.92 9/30/2016 4:31:05PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger III Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,068.51 81.00 91.90 144.36 6,200.59 9.71 70.49 10.02 Hold for 1516.86' 11,100.00 81.00 91.90 144.36 6,199.54 9.71 70.49 10.02 11,200.00 81.00 91.90 144.43 6,196.23 9.82 70.63 10.13 11,300.00 81.00 91.90 144.51 6,192.92 9.94 70.81 10.25 11,400.00 81.00 91.90 144.61 6,189.61 10.08 71.01 10.38 11,500.00 81.00 91.90 144.71 6,186.29 10.23 71.24 10.52 11,600.00 81.00 91.90 144.83 6,182.98 10.39 71.50 10.68 11,700.00 81.00 91.90 144.95 6,179.67 10.56 71.79 10.84 11,800.00 81.00 91.90 145.09 6,176.36 10.74 72.11 11.02 11,900.00 80.80 91.90 144.31 6,173.05 9.70 70.31 10.01 12,000.00 80.80 91.90 144.34 6,169.73 9.76 70.35 10.06 12,100.00 80.80 91.90 144.36 6,166.42 9.81 70.40 10.12 12,200.00 80.80 91.90 144.39 6,163.11 9.87 70.46 10.18 12,300.00 80.80 91.90 144.41 6,159.80 9.93 70.51 10.24 12,400.00 80.80 91.90 144.44 6,156.48 10.00 70.58 10.30 12,500.00 80.80 91.90 144.47 6,153.17 10.07 70.65 10.37 12,585.37 80.80 91.90 144.50 6,150.34 10.14 70.72 10.43 Start 2°/100'DLS,-126.47°TF,for 126.67' 12,600.00 80.80 91.90 144.50 6,149.86 10.14 70.72 10.43 12,635.65 80.80 91.90 144.52 6,148.68 10.16 70.74 10.46 12,700.00 79.44 90.86 144.53 6,147.13 10.21 72.33 10.26 12,709.60 79.23 90.70 144.53 6,147.00 10.22 72.56 10.24 12,712.03 79.23 90.70 144.54 6,146.97 10.29 72.59 10.31 Hold for 1386' 12,800.00 79.23 90.70 144.54 6,145.89 10.29 72.59 10.31 12,900.00 79.24 90.70 144.58 6,144.66 10.36 72.67 10.39 13,000.00 79.24 90.70 144.62 6,143.44 10.45 72.76 10.47 13,100.00 79.24 90.70 144.65 6,142.21 10.53 72.85 10.55 13,200.00 79.24 90.70 144.70 6,140.99 10.61 72.95 10.64 13,300.00 79.24 90.70 144.74 6,139.76 10.70 73.05 10.73 13,400.00 79.24 90.70 144.78 6,138.53 10.79 73.15 10.82 13,500.00 79.24 90.70 144.83 6,137.31 10.89 73.26 10.91 13,600.00 79.24 90.70 144.87 6,136.08 10.98 73.38 11.00 13,700.00 79.24 90.70 144.92 6,134.85 11.08 73.49 11.10 13,800.00 79.24 90.70 144.97 6,133.63 11.18 73.62 11.20 13,900.00 79.24 90.70 145.03 6,132.40 11.28 73.74 11.30 14,000.00 79.25 90.70 145.08 6,131.17 11.38 73.88 11.40 14,095.60 79.25 90.70 145.13 6,130.00 11.48 74.00 11.50 14,098.03 79.37 90.64 145.14 6,129.97 11.48 73.88 11.50 Start 3.5°/100'DLS,139.35°TF,for 176.83' 14,100.00 79.37 90.59 145.14 6,129.95 11.48 73.88 11.50 14,200.00 81.92 87.93 145.13 6,131.24 11.59 70.94 11.99 14,272.43 83.60 86.01 145.13 6,135.07 11.67 68.75 13.08 9/30/2016 4:31:05PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39©159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 14,274.86 83.60 86.01 145.13 6,135.24 11.68 68.75 13.09 Hold for 7.79' 14,280.22 83.60 86.01 145.13 6,135.62 11.68 68.75 13.09 14,282.65 83.98 86.09 145.14 6,135.78 11.70 68.39 12.73 Start 3.5°/100'DLS,25.16°TF,for 125.93' 14,300.00 83.98 86.64 145.14 6,136.88 11.70 68.39 12.73 14,400.00 85.71 89.80 145.20 6,139.99 11.81 66.55 11.81 14,406.15 85.81 90.00 145.20 6,140.00 11.81 66.44 11.81 14,408.58 85.87 89.96 145.21 6,140.00 11.82 66.36 11.82 Start 2°/100'DLS,155.34°TF,for 6.62' 14,412.77 85.87 89.88 145.21 6,140.01 11.82 66.36 11.82 14,415.20 85.87 89.88 145.23 6,140.01 11.92 66.41 11.92 Hold for 516.05' 14,500.00 85.87 89.88 145.23 6,140.19 11.92 66.41 11.92 14,600.00 85.87 89.88 145.29 6,140.40 12.03 66.56 12.03 14,700.00 85.87 89.88 145.35 6,140.61 12.15 66.71 12.15 14,800.00 85.87 89.88 145.42 6,140.82 12.26 66.87 12.27 14,900.00 85.87 89.88 145.49 6,141.03 12.38 67.04 12.38 14,928.82 85.87 89.88 145.51 6,141.09 12.41 67.09 12.42 14,931.25 85.23 89.92 145.55 6,141.09 12.50 67.99 12.60 Start 2°/100'DLS,-24.66°TF,for 89.81' 15,000.00 85.23 91.17 145.55 6,140.44 12.50 67.99 12.60 15,018.63 85.05 91.51 145.56 6,140.00 12.52 68.23 12.70 15,021.06 85.05 91.51 145.62 6,139.94 12.62 68.36 12.79 Hold for 1894.86' 15,100.00 85.05 91.51 145.62 6,137.85 12.62 68.36 12.79 15,200.00 85.05 91.51 145.69 6,135.21 12.74 68.54 12.91 15,300.00 85.06 91.51 145.76 6,132.58 12.87 68.72 13.03 15,400.00 85.06 91.51 145.83 6,129.94 12.99 68.90 13.16 15,500.00 85.06 91.51 145.91 6,127.30 13.12 69.09 13.28 15,600.00 85.06 91.51 145.99 6,124.66 13.24 69.29 13.41 15,700.00 85.06 91.51 146.07 6,122.02 13.37 69.49 13.53 15,800.00 85.06 91.51 146.15 6,119.38 13.50 69.69 13.66 15,900.00 85.06 91.51 146.23 6,116.74 13.63 69.90 13.79 16,000.00 85.06 91.51 146.32 6,114.10 13.76 70.11 13.92 16,100.00 85.06 91.51 146.40 6,111.47 13.90 70.32 14.05 16,200.00 85.06 91.51 146.49 6,108.83 14.03 70.54 14.19 16,300.00 85.07 91.51 146.58 6,106.19 14.16 70.77 14.32 16,400.00 85.07 91.51 146.67 6,103.55 14.30 70.99 14.45 16,500.00 85.07 91.51 146.76 6,100.91 14.44 71.23 14.59 16,600.00 85.07 91.51 146.85 6,098.27 14.58 71.46 14.72 16,700.00 85.07 91.51 146.95 6,095.63 14.71 71.70 14.86 16,800.00 85.07 91.51 147.05 6,092.99 14.85 71.94 15.00 16,900.00 85.07 91.51 147.14 6,090.36 14.99 72.19 15.14 16,913.49 85.07 91.51 147.16 6,090.00 15.01 72.22 15.16 9/30/2016 4:31:05PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan 2S-13:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan 25-13:120+39 @ 159.00usft(Doyon142) Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp22 Database: OAKEDMP2 1 Casing Points Measured Vertical Casing Hole DepthDepth Diameter Diameter (usft) (usft) Name (") C') 9,141.50 5,939.07 10 3/4"x 13-1/2 10-3/4 13-1/2 10,315.90 6,332.00 7-5/8"x 9-7/8" 7-5/8 9-7/8 16,915.92 6-3/4"x 4-1/2" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 9,471.37 6,089.80 U Kalubik 0.00 9,219.53 5,974.80 THRZ 0.00 10,250.60 6,322.80 A3 0.00 10,003.08 6,272.80 A4 0.00 9,676.24 6,171.80 Kalubik(K-1) 0.00 9,960.35 6,261.80 Kup C(Top C4) 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,033.19 5,885.32 -1,063.80 -5,478.30 KOP:3.5°/100'DLS,70.23°TF,for 86.11' 9,119.30 5,928.45 -1,002.33 -5,520.42 Start 9.65°/100'DLS,-30°TF,for 22.2' 9,141.50 5,939.07 -986.06 -5,531.16 Hold for 28.5' 9,170.00 5,952.30 -965.13 -5,545.28 Start 3°/100'DLS,-30°TF,for 60' 9,230.00 5,979.43 -921.04 -5,575.60 Adjust TF to 171.81°,for 77.72' 9,307.72 6,015.01 -864.32 -5,615.05 Hold for 18.85' 9,326.57 6,023.98 -850.68 -5,624.47 Start 3.5°/100'DLS,58.18°TF,for 989.34' 10,315.90 6,332.00 22.41 -5,928.08 Hold for 20' 10,335.90 6,334.56 42.16 -5,929.98 Start 3°/100'DLS,64.95°TF,for 732.61' 11,068.51 6,359.59 765.38 -5,856.87 Hold for 1516.86' 12,585.37 6,309.34 2,238.23 -5,497.63 Start 2°/100'DLS,-126.47°TF,for 126.67' 12,712.03 6,305.97 2,361.47 -5,468.57 Hold for 1386' 14,098.03 6,288.97 3,715.57 -5,173.41 Start 3.5°/100'DLS,139.35°TF,for 176.83' 14,274.86 6,294.24 3,886.71 -5,129.58 Hold for 7.79' 14,282.65 6,294.78 3,894.17 -5,127.39 Start 3.5°/100'DLS,25.16°TF,for 125.93' 14,408.58 6,299.00 4,014.30 -5,089.96 Start 2°/100'DLS,155.34°TF,for 6.62' 14,415.20 6,299.01 4,020.58 -5,087.88 Hold for 516.05' 14,931.25 6,300.09 4,510.64 -4,926.18 Start 2°/100'DLS,-24.66°TF,for 89.81' 15,021.06 6,298.94 4,596.11 -4,898.63 Hold for 1894.86' 16,915.92 TD:16915.92'MD,6249'TVD Checked By: Approved By Date: 9/30/2016 4:31:05PM Page 6 COMPASS 5000.1 Build 74 Pool Report • • d l,b£1 J1 N O M CDN s ,..as6ET 1> k 2 A WASP L� Q 0 2.:1�P O 000000.0 amm mm p W No00o0 o0U `�Q ',, ',, O 0'•, Q z '61)\'''1/4'1+' O 0 0 CO 0 0 a N. .1 3888 O ocvmmmoo� h ^pj NNNNNMMM M �N r�o`,o,om,a,o�� F O o N 34 0 O 0 o I:fl : • 0:e 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F71713100.0020 FEL 11672.2385 Transform Quit Help • i 2S-13A Surface Casing r. 1,7' i'r CPAt Coordinate Converter Ia From: r To: is Datum: NAD83 �I Region: alaska J Datum: 1NAD27 Region: alaska �:..1 Latitude/Longitude ID ecimal Degrees _71C Latitude/Longitude !Decimal Degrees C UTM Zone: I" South C UTM Zone: True r South I ( State Plane Zone: q Units: jus-ft i 4State Plane Zone: q , Units: us-ft . 1 C Legal Description(NAD27 only) C Legal Description(NAD27 only) t —Starting Coordinates: —Ending Coordinates: X: 11620189.66 X: 1480156.309044093 , Y: 15929072.10 Y: 1 5929322.54015045 Transform I Quit 1 Help 1 ... . ..; a ..: X o From: n To: Datum: 1NAD83 ..,:j Region: alaska zi Datum: NAD27 Region: jalaska _II 1 Latitude/Longitude ID ecimal Degrees y:! r Latitude/Longitude 1Decimal Degrees t" UTM Zone:l r South r UTM Zone: True rSouth C+ State Plane Zone: q Units: us-ft . C State Plane Zone: q Units: us-ft i i Legal Description(NAD 27 only) re. Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1620189.66 1 Township: 1010 FIE; Range: 008 E Y: 15929072.10 Meridian: 11-1---A, Section:117 Fr". 13728.1278 FEL • 12414.3998 ) Transform I Quit I Help I ` • • 1 2S-13A Intermediate 1 Casing 113. CPAI Coordinate Conver - -1-0!-- -:e r"'0:0'..0'00"sseres. 1.-Dercs:, - • -...;- ;.es •••• cs, ::0:0".--ser0=1:44411, • X From: i To: Datum: 1NAD83 !!!!ri Region: lalaska _71 Datum: 1NAD27 ,I Region: lalaska zi 0 r Latitude/Longitude !Decimal Degrees !!... I' Latitude/Longitude !Decimal Degrees szi C UTM Zone: r South r UTM Zone.. r"--- IT rue r South (' State Plane Zone: 4 ,. Units: FT .,,, ' State Plane Zone: 4Units: lus-ft .1 C Legal Description(NAD27 only) r Legal Description(NAD27 only) -Starting Coordinates: -Ending Coordinates: X: 11615398.28 X: 1 475364.818059672 ,-- Y: 15928726.61 Y: 1 5928977.12516587 I r . • • • .. 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Units: us-ft ✓ Leoal Description)l1,1`-),[ only) Legal Description(NAD27 only] m Starting Coordinates: Legal Description X: 1615055.69 Township: 010 N Range: 008 E Y: 5929430.33 Meridian: 17,, Section:118 i �� 1FNL _7.1 13385.0373 FEL 12268.8438 Transform Quit I Help I • to r2S-13A Production Horizon --,14----. .---fts....:.. .. Fa. CPAI Coordinate Converter -,irr,v.v-:-'''' -' - -From. To: Datum: !NAP 83 v Region: lalaska „z.1 Datum: 1NAD27 ...1 Region: lalaska J C Latitude/Longitude !Decimal Degrees C r Latitude/Longitude !Decimal Degrees ...:1 C UTM Zone:1 r South C UTM Zone: True r South aState Plane Zone: 4 A Units: lus.ft ,./1 a° State Plane Zone: T-. Units: lus-ft A C Legal Description(NAD27 only) C Legal Description[NAD27 only) -Starting Coordinates: [Ending Coordinates: X: 11615011.64 X: r'i74'F8.1135IEF02"— : Y: 15929656.68 Y: 1 5929917.18150047 Transform , Quit I Help Prf, CPAI Coordinate.Conxet,...,, 4.4-1- :11 ' . . _,.., . . i From: To- . 1 Datum: NAD83 2ri Region: lalaska A Datum: NAD27 , Region: Jalaska 2,,J C Latitude/Longitude !Decimal Degrees .... C Latitude/Longitude !Decimal Degrees .1 l C UTM Zone:1 r South ( UTM Zone: True r South I I (1`.' State Plane Zone:14.--E Units: 17"-E. r State Plane Zone:17",, Units: jusirE. k C Legal Description(NAD27 cirgrii 4° Legal Description(NAD27 only) r-Starting Coordinates: Legal Description X: 11615011.64 Township: 1F6— EFEE. .. Range: Y: 15929666.68 Meridian: p., Section:118 I :' IFNr . 13148.8247 FEL , 12312.7801 Transform 1 .. Quit i _ _Help j ti m3. • III 2S-13A TD n, CPAI Coordinate Converter:" –From: To: Datum: 3NAD83 j Region: 3alaska J Datum: 3NAD27 �J Region: alaska ✓ Latitude/Longitude Decimal Degrees zi C Latitude/Longitude 1Decimal Degrees +_ ✓ UTM Zone: (" South C UTM Zone::True r South C* State Plane Zone:14 zalI Units: us-ft + C+ State Plane Zone: 4 + Units: 17;37,3 C Legal Description(NAD27 only) C Legal Description(NAD27 only) r Starting Coordinates: –Ending Coordinates: X: 11616619.00 X: 1 476585.685309586 Y: 15936109.00 Y: 15936359.3455806 Transform Quit I Help ,-,-- m,, a f a a In CP-41 Coordinate Converter.. ' a` x From: –To: Datum: 3NAD83 ..".1 Region: alaska Datum: NAD27 zj Region: lalaska_. , I ✓ Latitude/Longitude ID ecimal Degrees +I I C Latitude/Longitude 1Decimal Degrees C UTM Zone: r South ` r UTM Zone: True r South C* State Plane Zone:14 Units: us-ft . r State Plane Zone: 4 + Units: us-ft + p 1 ✓ Lee.:[e ,ription(NAD27:only C. Legal Description(NAD27 only) I –Starting Coordinates: r Legal Description 1 X: 11616619.00 Range: ' Township: 010 N 1008 E Y: 5936109.00Section: Meridian: 17—%2; 7 FE'''. 11980.8720 FEL + 1701.97117 Transform Quit 3 Help As - built REV, DATE BY CK APP • DESCRIPTION ,REV DATE BY • APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 per K150013ACS NOTES: ,w w 18 11 +8 16 + 1 2 1 i$ n.3 DMA. ._.xx 111.1,11.1CR +11. BASIS OF LOCATION AND ELEVATION IS DS2S , 93 30 T.. MONUMENTATION PER LOUNSBURY Sc ASSOC. !� "�`� �� 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, '° as 2 3 I �1 ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ..../ro ' . ARE NAD 27. w 31 0G 9..` 3e 3of caw — 2., f\P f v ww - T1 ON 3. ELEVATIONS ARE B.P.M.S.L. °' iti V5;..911,54,\ � li +- 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED � / Q�Q, e INK SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, %�P�S'° ° 1 0 UMIAT MERIDIAN. 18 O 13 13 18 +1 16 1s 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS ; L15-28, L15-29, L15-32, L15-35, 11-13-2015 FIELD BOOK L15-75. 4 t9 21 I 2423 18 �° 33 PROJECT LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. a 20 Y 2. 27 z 30 28 .8 21 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 1 3. Y. 3'.. 32 33 34 33 eg, 31 32 33 32 N VICINITY MAP NTS 4171 r 6 30 �r DS2S 4 • • 14 12 .1 • • . . •5• 3• 2 1 • 9o 7 13. 15 11 LEGEND ® AS—BUILT CONDUCTOR LOCATION 17 16 • EXISTING CONDUCTOR LOCATIONS 20+21 GRAPHIC SCALE 0 100 200 400 SEE PAGE 2 OF 2 FOR LOCATIONS 0. LOUNSBURY& ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS 1110./ AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK6 9d24 5/28/15 DRAWING No. CEA—D2SX-6219D24 (PART: 1 OF 2 I REV: 2 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN" Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112,0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' * 13 5,929,948.70 480,898.09 70° 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. cp.•. 9F e+� . � ��� SURVEYOR'S CERTIFICATE _ Ov.s 1 49 %\ %*�� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF • ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY �" JEREMIAH F. CDRNELL' �� � DONE BY ME OR UNDER MY DIRECT SUPERVISION AND • "� �, THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT s���., LS-12663 AS OF NOVEMBER 13, 2015. LOUNSBURY -r & ASSOCIATES, INC. SURVEYORSRENGINEERS PLANNERS P AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips GOND WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD ALE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 FxRi44ARsg 2 x ry • • Attachment 3 - 2S-13A Drilling Hazards Summary 9-7/8"Intermediate#2 Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Moderate Lost circulation has occurred on offset wells 2S-07&2S- 02 in the immediate hole. Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tarn formations crossed in intermediate. Apply wellbore strengthening mud additives. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Production Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. S Attachment 4 — 2S-13A Cement Summary 7-5/8"Intermediate#2 Liner run to TD(a,10,316'MD/6,332' TVD bring cement to liner top(i 8958' MD/5846' TVD Cement from 10,316' MD to 8,958'with 15.8 ppg Class G(-180' inside 10-3/4"liner). Assume 40%excess annular volume. Tail slurry: (10,316'—9,138')X 0.2145 ft3/ft X 1.4(40%excess)=354 ft3 annular volume (9,138-8,958')X 0.2145 ft3/ft X 1.0(0%excess)=39 ft3 annular volume 80' X 0.2483 ft3/ft=20 ft3 shoe joint volume Total volume=354 ft3+39 ft3+20 ft3=>353 Sx @ 1.17 ft3/sk System: 353 Sx 15.8 ppg Class G OF 714.� • v7y ep THE STATE Alaska Oil and Gas Of Conservation Commission _ ALA S :A sir = 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA ,�,� Fax: 907.276.7542 www.aogcc.alaska.gov G. Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-13A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-104 Surface Location: 3099.9' FNL, 1672.2' FEL, SEC. 17, T1ON, R8E, UM Bottomhole Location: 1911.3' FNL, 851.9' FEL. SEC. 7, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster , Chair DATED this fay of September, 2016. "C :, , STATE OF ALASKA A OIL AND GAS CONSERVATION COMIPON AUG2016 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑✓ ' Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑✓ • Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone I Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q• Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 ' KRU 2S-13A' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16958'• TVD: 6249' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3099.9'FNL,1672.2'FEL,SEC17,T1 ON,R8E,UM ADL 25603,25590 . Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3079.5'FNL,2320.4'FEL,SEC18,T1ON,R8E, UM 2677,2678,2675 10/1/7016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1911.3'FNL,851.9'FEL,SEC7,T1ON,R8E,UM 2512,2501 2741.5'from ADL380051 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 158.5 % 15.Distance to Nearest Well Open Surface: x-480,898.10' y-5,929,948.79' Zone-4 • GL Elevation above MSL(ft): 119.8 • to Same Pool: 1683.7'f/25-14 16.Deviated wells: Kickoff depth: 9138 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92 degrees% Downhole: 3840 Surface: 3209 ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 9.875 7.625 29.7 L-80 HYD563 10277' 39' 39' 10316' 6332' 353 sx 15.8 ppg Class G 6.75 4.5 12.6 L-80 IBTM 6758' 10200' 6314' 16958' 6249' N/A 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 16878.5 6216.9 RHC 9758 9926.5 6261.5 9926.5 Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 20" 117.5' 117.5' Surface 2807.7' 13.375" 1460 sx 11.0 ppg&278 sx 12 ppg 2847.1' 2559.3' Intermediate 6631.84' 10.75" 1535 sx 15.8 ppg Class G 9329.5' 6029.5' Production 10407.83' 7.625" 348 sx 15.8 ppg class G 10445.72' 6331.5' Liner 6860.34' 4.5" N/A 16841.11' 6245.5' Perforation Depth MD(ft): N/A Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date Y-2-.7- !c. 22.I hereby certify that the foregoing is true and the procedure approved herein will not Scott Brunswick 263-4249 be deviated from without prior written approval. Contact scott.a.brunswick(a)cop.com Email Printed Name G.Chip Alvord Title AK Drilling Manager r Signature ✓ L_ tc( Phone 265-6120 Date E: 2i12 -14, Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: c21( -101 50-103•••a o 7,0-o!-CQ Date: q(RA(I l.p requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: Other: Bo P I t s-,f te) 3506 5-/ 1 Samples req'd: YesR Noy Mud log req'd:Yes❑ No V ff v/ 4 r� [�l�t��fv 1�7 z s 6 G P y2S measures: Yes No❑ Directional svy req'd:Yes[v'No❑ Spacing exception req'd: Yes❑ No " Inclination-only svy req'd:Yes❑ No[ Post initial injection MIT req'd:Yes No APPROVED BY Approved by:ai6eiv COMMISSIONER THE COMMISSION Date::l6j-/4 K.6 .3ifi VW- c7//5//6 Submit Form and Form 10-401(Revised 11/2015) approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-13A Saved:29-Aug-16 Post Office Box 100360 Anchorage, 99510-0360 Phone(907)263-4249 in coPil i s Email: scott.a.brunswickOconocophillips.com August 29,2016 Alaska Oil and Gas Conservation Commission 333 West'7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-13A A3 Sand Pre-Produced Injector. Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to re-drill of an onshore pre-produced injector well from the 2S pad. The expected spud date for this well is October 1,2016. It is planned to use rig Doyon 142. Well 2S-13 was spudded in November 2015,however,ConocoPhillips encountered problems pulling the whipstock assembly out of the 7-5/8"production casing after drilling to TD of the 2S-13L1 lateral. Numerous fishing attempts were performed trying to fish the whipstock out of the hole in order to complete the well as designed with no success. ConocoPhillips requested&gained approval to shutdown operations(Sundry 316-073),run a kill string, and suspend the wellbore for a future return to fish the whipstock,regaining access to the 2S-13 lower lateral,and attempt to run the liner in the 2S-13L1 upper lateral&complete the well as permitted under 215-152. While the rig was away, ConocoPhillips was able to run a downhole camera to evaluate the condition of the whipstock& window. The camera images showed shale collapsed onto the whipstock to the point the whipstock could not be seen. Due to the condition of the window&risk of fishing, ConocoPhillips Os previously submitted a sundry to abandon based on the current plan is to abdon the 2S-13 &2S-13L1 laterals./Once cement has been pumped to abandon the laterals with Doyon142,the operation will be to cut&pull 7-5/8"casing in order to use a whipstock in the 10-3/4"liner &re-drill the intermediate#2 hole section. A 7-5/8"liner will be run&set into the Kuparuk formation with a he-back string back to surface. Once this operation is complete,the well will be set up to drill the multi-lateral as originally planned. Both laterals will be drilled with 6-3/4"bits, and subsequently lined with 4-1/2"liner with pre-perforated pups. An LEM junction system will be used for the upper A4 lateral. 4-1/2"tubing will be run back to surface. The current 2S-13A &2S-13L1 laterals well names will remain the same in order to keep all records internally& externally correct. The new laterals will become 2S-13A(lower A3 lateral), &2S-13A L1 (upper A4 lateral) respectively. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. • • Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 (scoff.a.brunswick(a,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, ios Scott Brunswick Drilling Engineer • • Application for Permit to Drill Document Milling Kuparuk Well 2S-13A Conocophilkps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-13A Location Summary Requirements of 20 AAC 25.005(c)(2) An application jroa Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat ident fving the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 3099.9' FNL, 1672.22 FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 159' AMSL Northings: 5,929,948.8' Eastings: 480,898.1' Pad Elevation 120'AMSL Location at Surface Casing 3728.0'FNL,2414.4' FEL, Sec 17,T10N,R008E,UM NGS Coordinates Measured Depth, RKB: 2,847' Northings: 5,929,322.6' Eastings: 480,156.3' Total Vertical Depth, RKB: 2,559' Total Vertical Depth, SS: 2,400' Location at 10-3/4" 3728.0' FNL,2414.4' FEL, Sec 17,T1ON,R008E,UM whipstock in Intermediate#1 10-3/4"Liner NGS Coordinates Measured Depth, RKB: 9,138' Northings: 5,928,946.86' Eastings: 475,384.67' Total Vertical Depth, RKB: 5,937' Total Vertical Depth, SS: 5,778' Location at Intermediate#2 3079.51' FNL,2320.4'FEL, Sec 18,T10N,R008E,UM 7-5/8"Casing NGS Coordinates Measured Depth, RKB: 10,316' Northings: 5,929,986.50' Eastings: 474,970.55' Total Vertical Depth, RKB: 6,332' Total Vertical Depth, SS: 6,173' Location at Total Depth 1911.3' FNL, 851.95' FEL, Sec 7,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 16,958' Northings: 5,936,429.34' Eastings: 476,435.68' Total Vertical Depth, RKB: 6,249' Total Vertical Depth, SS: 6,090' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.O5O(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. • • The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-13A is calculated using an estimated maximum reservoir pressure of 3,840 psi (11.7 ppg , based on MPD draw down test of 2S-13 toe), a gas gradient of 0.10 psi/ft, and the estimated dep h of the Kuparuk A3 sand at 6,312' TVD: A Sand Estimated. BHP = 3,840 psi A Sand estimated depth = 6,312' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 631 psi (6,312' TVD * 0.10 psi/ft) MPSP=BHP—gas column =3,209 psi (3,840 psi—631 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-13A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(51 An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030 f; A procedure is on file with the commission for performing LOT's. • • Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole weigh Length Top MD/TVD Btm MD/TVD OD(in) Size t(Ib/ft) Grade Conn. (ft) ( � ( ) Cement Program 20 36 78.7 H-40 Welded 78 Surf 117.5'117.5' Pre-installed&cemented Hydril2847.1'/ Existing cement to Surface with 559. 13-3/8 16 68 L-80 563 2807.7' Surf 247.1 1460 sx Lead 11.0 ppg, 278 sx Tail Slurry 12.0 ppg 12-1/4 Hydril9329.5'/ Existing cement to above C-37 10-3/4 x 13- 45.5 L-80 521 6631.8' 2697'/2449' 6029.5' 1535 sx 15.8 ppg Class G 1/2 7-5/8 9-7/8 29.7 L-80 Hydril 10,277' Surf 10,316/6,332 Cement to inside 10-3/4"liner 563 353 sx 15.8 ppg Class G 4-1/2 6-3/4 12.6 L-80 IBTM 6,758 10,200/6,314 16,958/6,249 N/A Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Surface hole has been drilled, BOPE will be installed. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Intermediate#2 Production 9-7/8" Hole 6-3/4" Hole 7-5/8" Liner& 4-1/2"Liner Tieback Flo-Thru Mud System LSND(WBM) (WBM) Density 10.5-11.8 10.5-11.8 PV 10 -20 25 -30 YP 16 -24 16—24 Initial Gel 10- 12 5 —8 10 minute Gel 10- 18 5 - 12 API Filtrate <6 <6 HTHP Fluid Loss at 160F < 10 < 10 pH 9.0- 10.0 9.5 - 10.0 • • Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A -Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. • • 1. End sundry to abandon for re-drill(previously submitted to AOGCC for approval on 8-23-16) 2. Orient&begin sidetracking to drill the landing intermediate section of 2S-13A. 3. Directionally drill to intermediate#2 hole TD of 10,316'MD/6,332' TVD landing in the Kuparuk A3 sand. 3.3.1.Utilize MPD to hold constant bottom hole pressure. 4. Circulate&rotate at maximum rates until shakers are clean with minimum of 3 bottoms up. 3.4.1.Perform MPD draw down formation pressure test&eight up mud system to kill weight as necessary. 5. Drop rabbit with 120'tail sling for liner run. 6. POOH on elevators racking back 5"drill pipe. (lay 5"DP down after the upcoming 7-5/8"liner run,this will minimize shale exposure time.) 7. Lay down intermediate BHA. 8. Swap out upper pipe rams for 7-5/8"solid body rams&test, 3500 psi high,250 psi low. 9. Run 7-5/8",29.7#L80, Hydril 563 liner. 10. Make up 7-5/8"liner hanger&fill liner tieback with"pal mix" 11. Run liner to TD on 5"drill pipe&break circulation for upcoming cement job. 12. Pump cement job as per Schlumberger proposal. Top cement placed inside above 10-3/4"liner shoe. 13. Space out the liner hanger to+/- 150' above the 10-3/4"window. 14. Space the packer element onto the 10-3/4"casing body avoiding a casing coupling&keep string in tension when setting the liner hanger. 15. Pressure up to set the liner hanger,slack off weight plus 20 Klbs,continue to pressure up to release the hanger running tool. 16. Bleed off pressure&check floats. 17. Pick up to check the HRD tool released. Pick up until dogs are above liner top. 18. Set down weight at the tool,rotating as necessary to get weight down. 19. After the packer is set,apply drill pipe pressure&pick up slowly to pull the RS pack off. Once the standpipe pressure drops,engage the pump&circulate out any residual cement. 20. Close the annular BOP&pressure test the packer to 1000 psi for 10 minutes. 21. POOH&lay down 5"drill pipe. 22. Pick up baker mule shoe with seal assembly. 23. Run the 7-5/8"tie-back string in hole. 24. After picking up the last joint before stabbing into seals,break circulation at 1-2 BPM. 25. Slowly run in hole watching the pressure increase&hookload indication as seals stab into the tie back extension. Mark entry&stack out depths. 26. Pressure test the 7-5/8"x 10-3/4"annulus with 1000 psi for 10 minutes to prove integrity of the seals. 27. Pull up above the tie back extension. 28. Pick up space out pups,hanger,&landing joint. Ensure casing hanger is not spaced out across annular BOP. 29. Close annular BOP. 30. Pressure test the 7-5/8"liner& 10-3/4"casing to 2000 psi for 10 minutes through the 7-5/8"x 10-3/4"annulus to prove wellbore integrity. 31. Displace LSND mud with brine&flow check for 10 minutes. • • 32. Circulate in inhibitive brine&freeze protect in the 7-5/8"x(10-3/4"& 13-3/8")annulus. Inhibited brine to 7- 5/8"tie-back bottom,and freeze protect to base permafrost. 33. Run in hole with 7-5/8"casing&sting the seals into the sealbore. 34. Land the casing hanger,back out landing joint, install pack off&test. 35. Pressure test the 7-5/8"OA to 2000 psi for 30 minutes to prove final integrity. 36. Lay down any remaining 5"DP. 37. PU 4"DP,6-3/4"bit, and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,LWD Sonic(for CBL)) 38. RIH to above shoe/cement&test intermediate casing to 3500 psi for 30 minutes. 39. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 13.5 ppg&maximum of 16 ppg EMW,record results. 40. Directionally drill 6-3/4"lower lateral hole geo-steering through the Kuparuk A3 sand to TD 16,958' MD/ 6,249' TVD as per directional plan(wp19). Apply MPD pressure while drilling lateral to keep constant bottom hole pressure. 41. Circulate hole clean and POOH. 42. Lay down Production BHA. 43. PU and run 4-1/2", 12.6#liner w/pre-perforated pups. The top of liner will be placed at+/-10,200' MD/6,314' TVD,allowing for @ least 100' of overlap in the 7-5/8"casing. The actual liner hanger setting depth will be determine as drilled&to allow for proper spacing of the multi-lateral equipment. 44. Set liner hanger. Slackoff and set liner top packer. 45. Monitor well for flow for 15 minutes 46. PT liner to 3,000 psi at surface for 30 minutes, chart results. 47. Flow check well for 30 minutes. 48. POOH with liner running tools and lay down. 49. Run whipstock&mill window 50. Mill window until top mill across pace&clean up window. 51. Perform formation integrity test to minimum of 13.5 ppg,maximum of 16 ppg EMW,recording results. 52. POOH with milling BHA. 53. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope) 54. RIH,orient through window, &tag bottom. 55. End 2S-13A PTD&begin 2S-13AL1 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for / temporary storage and eventual processing for injection down an approved disposal well, or stored,tested for hazardous • ! substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Summaries 0 • Attachment 1 — Proposed Well Schematic 2S-13A & A L1 Dual Lat Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic D142 RKB [6. Last Edited:SAB-8/26/16 20"Conductor to-117.5' CT7J 16"Surface Hole 4-14"IBTM Tbing ci_J Surface Casing 13-3/8"68#L-80 HYD 563 2,847.1'MD/2,559.3'TVD 10-3/4"Planned TOC:5,491.5'(at minimum 12-1/4"X 13-1/2" Intermediate#1 Hole 500'MD above C37) C 3 . ,851.5'MD/4,659.5'TVD €. € 7-5/8"x 10-%"Liner Top.Packer 8,939.5'MD/5,837.5 TVD - Growler-AA(Iceberg):7,233.5'MD/4,867.5 TVD Top/Cairn 8,217 5'MD/.5,443.5'TVD (1/40 , Top Bermuda: 8,371.6 MD/4,529.5'TVD R10_,"Whipstock bottom of Window 9,138'MD/5,937.5'TVD 1. 3/1 INTtN Linor HRZ 9219'MD/5,975'TVD 10-3/4"45.6#L-80 Hyd521 9,329.5'MD/6,029.5'TVD Lower Kalubik(K-1 Marker):9,675'MD/6,172'TVD a Lateral Entry Module(LEM),Baker,w/seal assembly&ZXP WS#1 ;..) 1_ packer abo/p " \ -------\' ‘-'4.) , , Tap Kupa ruk C.9,960'MD/6,262'T VD Kruk A4;10043'MD/6273.T , I -E' I J 2513PB1/2S-13/2S-13L1 - 1 7-5/8 Whipstock'rap'of Window 9,999'M /6,272'.TVD RS-13L1 A4 TD 17,018'MD/6215'TVD 7-5/8"Flex Lock Liner Harrier/ZXP 10,200'MD/6 314'TVD Kuparuk A3:10252'MD/6323 TVD - ® 6/'OraSM1oenge Peel ':Qd _ .25:13A3TD;16958'MD/6249 TVD., intermediate Casing 7-5/8"29.7#L-80 Hyd563 Casing 10,316'MD/6,332' 6-3/4"Production Hole TVD(83°) Production liner. 4-Y::"liner w/pre-perforated pips • • Attachment 2 — 2S-13A Directional Plan • • 2S-13Awp19 7.022 Plan Summary _ - -----7-""--NN. >.5- ! THRITQ)C4) -5 •1\ht > - nv N ' vN1 , t I )1\ill\t Y �r 0 t 0 7 i 13-3/8"x 16� I I 1 I T f I 0 0 4000 8000 12000 16000 Measured Depth o-1-g3/8"x 161' Geodetic Datum: North American Datum 1983 ��l `` Depth Reference: Plan:119.8+39(Doyon 142)©158.80usft *4'9 o° Rig: ®®__//', �� a yo 00 r _ COo ^000 O I7-5/8"x 9-5/8'� 14 1/2"x 6-3/4'1 1111111i111-/ O , BOO OO ,o ° a ,, o 0 o R a. o rn 1 01° I t'v ,ol v �1 I 1 2 �I I - 0 o cn 9033 9932 0 1500 3000 4500 6000 7508 da00 1050E 12000 013500 0 9932 - 10112 Horizontal Departure 10112 - 10302 330 `_. 30 10302 - 10482 F � 10482 - 10852 ii - /'/ i. - c0 __. ... _ �_ ///j//A r,y/" � ii0 10852 110320 Is: 60 1 __. 300/ ' .. "pi, �,iiidi� - •' / it 11032 - 11212 at CO i ci. _ .. /�I .. � Ir � 11212 11452 ,5-n ,1452 11692 / - 11692 11922 i270 � 11922 - 12162 - . ,iji 1 I �� y f� �r r �� r �� 12162 - 12402 YY t. _. _ __ 1... I i f 1 I 9'itre d® 12402 - 12632 U _.. _. .. _ ..) i... .: � , ��(x I 12632 - 12872 h � �, t0 ,,Jf ii ..... \a`� IN 1 f;�/,4X11/ �1�I�1 ,2672 - 13112 I I I I t I I I I I I I 1 1 T I \VS W �! ,�IQ t( 4 . 13112 - 13582 0 2500 5000 7500 10000 12500 15000 17500 240 01. A% i� At� \ A,r.d,i I A 120 13582 - 14052 'a0r�0 P 10 1 14052 - 14522 SURVEY PROGRAM I# ��� ����� !'\��fl�� 14522 - 14992 Depth From Depth To Survey/Plan Tool I � -` 10" si13Pe1 14992 - 15472 h. 94.18 1295.08 2S-13PB1 Srvy#1-SLB NSG+Battery+SaQ'(2S©OPE6) 210 ' lfh 15472 15942 1316.29 2787.04 2S-13PB1 Srvy#2-SLB MWDi6/B(1�,6F(RS413129.2-SC 2879.51 9033.19 2S-13PB1 Srvy#3-SLBMWD4EMEIR'FSAASE -SC 180 15942 ""` 16412 9033.19 9450.00 25-13Awp19(Plan 2S-1A) INC+TREND CASING DETAILS 16412 - 1se7s 9450.00 10316.00 25-13Awp19(Plan 2S-13A) MWD 9450.00 10316.00 25-13Awp19(Plan 2S-13A) MWD+IFR-AK-CAZ-SC TVD MD Name M10316.00 11300.00 25-13Awp19(Plan 2S-13A) MWD 6331.80 10315.83 7-5/8"x 9-5/8" Magnetic Model: BGGM2016 T 10316.00 16957.32 2S-13Awp19(Plan 2S-13A) MWD+IFR-AK-CAZ-SC 6248.80 16957.32 4 1/2"x 6-3/4" Magnetic Model Date: 30-Nov-16 MagneticnDeclic etion: 1a Tru° d1 To convert a Magnetic Direction to a True Direction,Add 17.71°East SECTION DETAILS . Sec MD Inc Azi TVD ON/-S +E/-W Dleg TFace VSect Target Annotation 1 9033.19 59.42 323.94 5885.32 -1063.80 -5478.30 0.00 0.00 -2873.33 2 9125.00 60.49 327.45 5931.30 -998.16 -5523.07 3.51 71.48 -2826.96 3 9138.00 61.90 326.53 5937.56 -988.61 -5529.28 12.50 -30.00-2820.11 -5974.8 4 9158.00 61.90 326.53 5946.98 -973.89 -5539.01 0.00 0.00-2809.61 5 9218.00 63.46 325.52 5974.52 -929.69 -5568.80 3.00 -30.00 -2778.26 6 9283.67 61.56 324.95 6004.83 -881.83 -5602.01 3.00 -165.09-2744.65 7 9316.42 61.56 324.95 6020.43 -858.25 -5618.55 0.00 0.00-2728.15 THRZ 8 10315.83 82.68 354.50 6331.80 22.31 -5928.09 3.50 58.58 -2006.58 2S-13A Tgt 0 7-5/8 081816 PB 9 10335.83 82.68 354.50 6334.35 42.06 -5929.99 0.00 0.00-1988.66 10 10844.81 91.62 9.95 6359.80 547.97 -5910.09 3.50 60.48 -1506.45 11 14037.55 91.62 9.95 6268.71 3691.47 -5358.87 0.00 0.00 1636.00 12 14102.26 90.00 10.00 6268.80 3755.20 -5347.67 2.50 178.08 1699.72 2S-13A Tgt 1 A3 081818 PB -6089.8 13 14266.87 90.00 14.12 6268.80 3916.14 -5313.29 2.50 90.00 1862.72 14 14499.98 90.00 14.12 6288.80 4142.21 -5256.44 0.00 0.00 2094.60 15 14696.69 90.00 21.00 6268.80 4329.64 -5197.14 3.50 90.00 2291.01 2S-13A Tgt 2 A3 081816 PB U Kalubik 16 14902.84 82.79 21.05 6281.74 4521.37 -5123.44 3.50 179.59 2496.38 17 15006.96 82.79 21.05 6294.83 4617.96 -5086.26 0.00 0.00 2599.86 18 15041.51 84.00 21.00 6298.80 4649.99 -5073.95 3.50 -2.43 2634.17 2S-13A Tgt 3 A3 081816 PB 19 15286.92 92.01 17.89 6307.34 4881.06 -4992.39 3.50 -21.29 2879.20 -6171.8 20 16957.32 92.01 17.89 6248.80 6469.72 -4479.59 0.00 0.00 4547.43 25-13A Tgt 4 A3 081816 PB Kalubik(K-1) 8277 C(Top C4) Permit Pack -i- A4 -6322.8 A3 ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Ifeanyi Ifesie QrQNi •N� O N Y N cap Norkiing (4000 usftlin) Y co '� r�`\iv� 3a4s co co Y Y ' N M N ►;r Y N Y - ' N Ei- J N to — _ O (NI- c',.1 - co M a1 N a _ - v 'Y Y o - N O Y co - Y J N �Y N O N i, r t` Cn O - v o i, 3� M — JN < N N 3� J 1�•' N O pOA O O r eo O O J •' N N p(�� - J (nNTTT___tJ _ _ 03 M O CL °. 1 3..' O co O (n co 0 O 3 N - O CO D M 0.1 N r _ N M •M N O - m O0 _ d d N O N C N el CV E N J J d lir O :. (13 co 2_—\\ - N . y�^q ' �_.y- 1 N E _ N N N CN \'� — 3a. V r — M /^; it, N L.L. (1.) - CV (13 CV r N 00 N 71 —� O a CO M •\' ,_ .e 00 II CA II N C1 N N ` N L� d V M -_ Ch N — co \ F} CV Cn Cn . N N O dN N N3 OO M M o M Z J co N N J +10 O O Z - N C2 NN ., M O _ C, CO gyp. - J M CV r oo _ N 3 _ d (13• M ,- N r W - co .l Co N - O ' O N �� J MJ - N J N — N J ��.1'c co p_ N _ — N , CO N Q41 fi - e-- V " rN Cz- J s._ N J I / / NN — M CV if - NN1j <N < V ,L-----?---------._c42< —N N M est - , J �/ co N p• M co N - D Z M N _ ) Co N W _ J N J a`I m , N N/� QI 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 �^ 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 c I (u!njsn Nov) 6u!LgioN 0 Qi • o 0 C) Q) 0 a) LO O ■I 0 N- 0 m OOO C. d a co 041COQ' o CLI 03 O CO m a. coco CO� 0-3- CO O < 0 o CO o CO 0(3O i-- co N < m ao 7 L.a) co H CO co = R1 QI— CD 0 �• Cl) CO CO Q CO 0 Q) N T- CO0 000 O in 4.. co � N N Cl) co ' -p O N i- O N i 1I � co 1 / I = \/O) I H ):Cl. I ~ \ 0005 CO 3 _ I I co _ o a� LO 1 VJ \ (13 N 1,..a _ 3 O o0 C) O __�_ o 4z. x0 V cQ O Ca. O N o 6V O Q in (3) M x O 0-� o I 0) C .Z N = 0 O a -O 0 a) 1 s s � O T O C o O O 0 O o O O i) O in Lr) co (ui/11sn o660 (+)111aoNT-)LITnoS ' • i 0 flco 1 1 I 11 o � o o m 2S-13• , .L I r o 2S-13Awp19 ------\- t ��••57 -o NEM V0 .100 o 0 co 0005 j Q o `Y' c 001il_ = I o 0 I'4000 -o LO LO Nr 0 0 0 a o� 4- 3000 O O r U 55 03. `1 o Y Y a , o O op nno� Y 1- co v -o V O cB 13 Uo , Q Q 2000 Cn Y . ` Co U O� �. \� \\� \� 1� •i � _ O -1000 - X 4�0 f 0 co Q. C) • szP \ ^�O ��• I ! O co .6) o- co M Q I I .e`+ M T"'"' I o 1l ql Lo o CO v N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LU 0 LU 0 LU (ui/l4sn 0090 u}dea �eai1aan anal o ~ Plan Report • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit fit Kuparuk 2S Pad 2S-13 Plan: 2S-13A Plan: 2S-13Awp19 44 Standard Proposal Report 24 August, 2016 G VC6' '" 0 • • ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Project Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site:+ Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design 2S-13Awp19 Project Kuparuk River Unit,North Slope Alaska,United States Site Kuparuk 2S Pad Site Position: Northing: Latitude: From: Map Fasting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 Well 2S-13 Well Position +Nl-S 0.00 usft Northing: Latitude: +El-W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 119.40 usft Ground Level: 119.80 usft Wellbore Plan:2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 11/30/2016 17.71 80.84 57,531 Design 2S-13Awp19 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,033.19 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 20.00 8/24/2016 2:47:08PM Page 2 COMPASS 5000.1 Build 74 • . ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design: 2S-13Awp19 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (1 (1 (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 9,033.19 59.42 323.94 5,885.32 5,726.52 -1,063.80 -5,478.30 0.00 0.00 0.00 0.00 9,125.00 60.49 327.45 5,931.30 5,772.50 -998.16 -5,523.07 3.51 1.17 3.82 71.48 9,138.00 61.90 326.53 5,937.56 5,778.76 -988.61 -5,529.28 12.50 10.85 -7.08 -30.00 9,158.00 61.90 326.53 5,946.98 5,788.18 -973.89 -5,539.01 0.00 0.00 0.00 0.00 9,218.00 63.46 325.52 5,974.52 5,815.72 -929.69 -5,568.80 3.00 2.60 -1.68 -30.00 9,283.67 61.56 324.95 6,004.83 5,846.03 -881.83 -5,602.01 3.00 -2.90 -0.88 -165.09 9,316.42 61.56 324.95 6,020.43 5,861.63 -858.25 -5,618.55 0.00 0.00 0.00 0.00 10,315.83 82.68 354.50 6,331.80 6,173.00 22.31 -5,928.09 3.50 2.11 2.96 58.58 10,335.83 82.68 354.50 6,334.35 6,175.55 42.06 -5,929.99 0.00 0.00 0.00 0.00 10,844.81 91.62 9.95 6,359.80 6,201.00 547.97 -5,910.09 3.50 1.76 3.03 60.48 14,037.55 91.62 9.95 6,269.71 6,110.91 3,691.47 -5,358.87 0.00 0.00 0.00 0.00 14,102.26 90.00 10.00 6,268.80 6,110.00 3,755.20 -5,347.67 2.50 -2.50 0.08 178.08 14,266.87 90.00 14.12 6,268.80 6,110.00 3,916.14 -5,313.29 2.50 0.00 2.50 90.00 14,499.98 90.00 14.12 6,268.80 6,110.00 4,142.21 -5,256.44 0.00 0.00 0.00 0.00 14,696.69 90.00 21.00 6,268.80 6,110.00 4,329.64 -5,197.14 3.50 0.00 3.50 90.00 14,902.64 82.79 21.05 6,281.74 6,122.94 4,521.37 -5,123.44 3.50 -3.50 0.02 179.59 15,006.96 82.79 21.05 6,294.83 6,136.03 4,617.96 -5,086.26 0.00 0.00 0.00 0.00 15,041.51 84.00 21.00 6,298.80 6,140.00 4,649.99 -5,073.95 3.50 3.50 -0.15 -2.43 15,286.92 92.01 17.89 6,307.34 6,148.54 4,881.06 -4,992.39 3.50 3.26 -1.27 -21.29 16,957.32 92.01 17.89 6,248.80 6,090.00 6,469.72 -4,479.59 0.00 0.00 0.00 0.00 8/24/2016 2:47 08PM Page 3 COMPASS 5000.1 Build 74 • S Comments apply th lin--a fore i,''' Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan: 119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design: 2S-13Awp19 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,726.52 9,033.19 59.42 323.94 5,885.32 5,726.52 -1,063.80 -5,478.30 2.66 -2,873.33 Start DLS 3.51 TFO 71.48 9,100.00 60.19 326.50 5,918.93 5,760.13 -1,016.37 -5,511.23 3.51 -2,840.03 9,125.00 60.49 327.45 5,931.30 5,772.50 -998.16 -5,523.07 3.51 -2,826.96 Start DLS 12.50 TFO-30.00 9,138.00 61.90 326.53 5,937.56 5,778.76 -988.61 -5,529.28 12.50 -2,820.11 Start 20.00 hold at 9138.00 MD 9,158.00 61.90 326.53 5,946.98 5,788.18 -973.89 -5,539.01 0.00 -2,809.61 Start DLS 3.00 TFO-30.00 9,200.00 62.99 325.82 5,966.41 5,807.61 -942.96 -5,559.73 3.00 -2,787.63 9,218.00 63.46 325.52 5,974.52 5,815.72 -929.69 -5,568.80 3.00 -2,778.26 Start DLS 3.00 TFO-165.09 9,218.63 63.44 325.52 5,974.80 5,816.00 -929.22 -5,569.11 3.00 -2,777.93 THRZ 9,283.67 61.56 324.95 6,004.83 5,846.03 -881.83 -5,602.01 3.00 -2,744.65 Start 32.76 hold at 9283.67 MD 9,300.00 61.56 324.95 6,012.61 5,853.81 -870.08 -5,610.26 0.00 -2,736.43 9,316.42 61.56 324.95 6,020.43 5,861.63 -858.25 -5,618.55 0.00 -2,728.15 Start DLS 3.50 TFO 58.58 9,400.00 63.11 327.75 6,059.23 5,900.43 -796.64 -5,659.56 3.50 -2,684.28 9,469.17 64.44 330.00 6,089.80 5,931.00 -743.53 -5,691.62 3.50 -2,645.33 U Kalubik 9,500.00 65.04 330.99 6,102.96 5,944.16 -719.26 -5,705.35 3.50 -2.627.23 9,600.00 67.04 334.14 6,143.57 5,984.77 -638.16 -5,747.43 3.50 -2,565.41 9,674.73 68.57 336.43 6,171.80 6,013.00 -575.31 -5,776.35 3.50 -2,516.25 Kalubik(K-1) 9,700.00 69.10 337.19 6,180.93 6,022.13 -553.65 -5,785.63 3.50 -2,499.06 9,800.00 71.21 340.16 6,214.88 6,056.08 -466.04 -5,819.81 3.50 -2,428.43 9,900.00 73.36 343.06 6,245.32 6,086.52 -375.66 -5,849.85 3.50 -2,353.77 9,959.86 74.67 344.76 6,261.80 6,103.00 -320.37 -5,865.80 3.50 -2,307.27 Kup C(Top C4) 10,000.00 75.56 345.89 6,272.11 6,113.31 -282.85 -5,875.63 3.50 -2,275.37 10,002.77 75.62 345.96 6,272.80 6,114.00 -280.24 -5,876.28 3.50 -2,273.15 A4 10,100.00 77.79 348.66 6,295.17 6,136.37 -187.94 -5,897.05 3.50 -2,193.52 10,200.00 80.04 351.39 6,314.40 6,155.60 -91.31 -5,914.04 3.50 -2,108.52 10,251.59 81.21 352.78 6,322.80 6,164.00 -40.90 -5,921.05 3.50 -2,063.55 A3 10,300,00 82.32 354.08 6,329.73 6,170.93 6.70 -5,926.53 3.50 -2,020.70 10,315.83 82.68 354.50 6,331.80 6,173.00 22.31 -5,928.09 3.50 -2,006.56 Start 20.00 hold at 10315.83 MD-7-518"x 9-518"-2S-13A Tgt 0 7-518 081816 PB 10,335.83 82.68 354.50 6,334.35 6,175.55 42.06 -5,929.99 0.00 -1,988.66 Start DLS 3.50 TFO 60.48 10,400.00 83.79 356.47 6,341.91 6,183.11 105.58 -5,935.01 3.50 -1,930.68 10,500.00 85.54 359.51 6,351.21 6,192.41 205.07 -5,938.50 3.50 -1,838.38 10,600.00 87.29 2.55 6,357.47 6,198.67 304.85 -5,936.703.50 -1,744.01 8/24/2016 2:47:08PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan: 119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design: 2S-13Awp19 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,201.85 10,700.00 89.06 5.57 6,360.65 6,201.85 404.53 -5,929.63 3.50 -1,647.92 10,800.00 90.83 8.59 6,360.75 6,201.95 503.75 -5,917.30 3.50 -1,550.47 10,844.81 91.62 9.95 6,359.80 6,201.00 547.97 -5,910.09 3.50 -1,506.45 Start 3192.74 hold at 10844.81 MD 10,900.00 91.62 9.95 6,358.24 6,199.44 602.30 -5,900.56 0.00 -1,452.13 11,000.00 91.62 9.95 6,355.42 6,196.62 700.76 -5,883.30 0.00 -1,353.71 11,100.00 91.62 9.95 6,352.60 6,193.80 799.22 -5,866.03 0.00 -1,255.28 11,200.00 91.62 9.95 6,349.78 6,190.98 897.68 -5,848.77 0.00 -1,156.86 11,300.00 91.62 9.95 6,346.95 6,188.15 996.13 -5,831.50 0.00 -1,058.43 11,400.00 91.62 9.95 6,344.13 6,185.33 1,094.59 -5,814.24 0.00 -960.01 11,500.00 91.62 9.95 6,341.31 6,182.51 1,193.05 -5,796.97 0.00 -861.58 11,600.00 91.62 9.95 6,338.49 6,179.69 1,291.51 -5,779.71 0.00 -763.16 11,700.00 91.62 9.95 6,335.67 6,176.87 1,389.97 -5,762.44 0.00 -664.73 11,800.00 91.62 9.95 6,332.85 6,174.05 1,488.42 -5,745.18 0.00 -566.31 11,900.00 91.62 9.95 6,330.03 6,171.23 1,586.88 -5,727.91 0.00 -467.88 12,000.00 91.62 9.95 6,327.20 6,168.40 1,685.34 -5,710.65 0.00 -369.46 12,100.00 91.62 9.95 6,324.38 6,165.58 1,783.80 -5,693.39 0.00 -271.03 12,200.00 91.62 9.95 6,321.56 6,162.76 1,882.26 -5,676.12 0.00 -172.61 12,300.00 91.62 9.95 6,318.74 6,159.94 1,980.71 -5,658.86 0.00 -74.18 12,400.00 91.62 9.95 6,315.92 6,157.12 2,079.17 -5,641.59 0.00 24.25 12,500.00 91.62 9.95 6,313.10 6,154.30 2,177.63 -5,624.33 0.00 122.67 12,600.00 91.62 9.95 6,310.27 6,151.47 2,276.09 -5,607.06 0.00 221.10 12,700.00 91.62 9.95 6,307.45 6,148.65 2,374.55 -5,589.80 0.00 319.52 12,800.00 91.62 9.95 6,304.63 6,145.83 2,473.00 -5,572.53 0.00 417.95 12,900.00 91.62 9.95 6,301.81 6,143.01 2,571.46 -5,555.27 0.00 516.37 13,000.00 91.62 9.95 6,298.99 6,140.19 2,669.92 -5,538.00 0.00 614.80 13,100.00 91.62 9.95 6,296.17 6,137.37 2,768.38 -5,520.74 0.00 713.22 13,200.00 91.62 9.95 6,293.34 6,134.54 2,866.84 -5,503.47 0.00 811.65 13,300.00 91.62 9.95 6,290.52 6,131.72 2,965.29 -5,486.21 0.00 910.07 13,400.00 91.62 9.95 6,287.70 6,128.90 3,063.75 -5,468.95 0.00 1,008.50 13,500.00 91.62 9.95 6,284.88 6,126.08 3,162.21 -5,451.68 0.00 1,106.92 13,600.00 91.62 9.95 6,282.06 6,123.26 3,260.67 -5,434.42 0.00 1,205.35 13,700.00 91.62 9.95 6,279.24 6,120.44 3,359.13 -5,417.15 0.00 1,303.77 13,800.00 91.62 9.95 6,276.42 6,117.62 3,457.58 -5,399.89 0.00 1,402.20 13,900.00 91.62 9.95 6,273.59 6,114.79 3,556.04 -5,382.62 0.00 1,500.62 14,000.00 91.62 9.95 6,270.77 6,111.97 3,654.50 -5,365.36 0.00 1,599.05 14,037.55 91.62 9.95 6,269.71 6,110.91 3,691.47 -5,358.87 0.00 1,636.00 Start DLS 2.50 TFO 178.08 14,100.00 90.06 10.00 6,268.80 6,110.00 3,752.97 -5,348.06 2.50 1,697.49 14,102.26 90.00 10.00 6,268.80 6,110.00 3,755.20 -5,347.67 2.50 1,699.72 Start DLS 2.50 TFO 90.00-2S-13A Tgt 1 A3 081816 PB 14,200.00 90.00 12.44 6,268.80 6,110.00 3,851.06 -5,328.65 2.50 1,796.31 14,266.87 90.00 14.12 6,268.80 6,110.00 3,916.14 -5,313.29 2.50 1,862.72 Start 233.11 hold at 14266.87 MD 14,300.00 90.00 14.12 6,268.80 6,110.00 3,948.27 -5,305.21 0.00 1,895.67 8/2412016 2:47:08PM Page 5 COMPASS 5000.1 Build 74 • ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design: 2S-13Awp19 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,110.00 14,400.00 90.00 14.12 6,268.80 6,110.00 4,045.25 -5,280.82 0.00 1,995.14 14,499.98 90.00 14.12 6,268.80 6,110.00 4,142.21 -5,256.44 0.00 2,094.60 Start DLS 3.50 TFO 90.00 14,500.00 90.00 14.12 6,268.80 6,110.00 4,142.23 -5,256.44 0.00 2,094.62 14,600.00 90.00 17.62 6,268.80 6,110.00 4,238.41 -5,229.10 3.50 2,194.34 14,696.69 90.00 21.00 6,268.80 6,110.00 4,329.64 -5,197.143.50 2,291.01 Start DLS 3.50 TFO 179.59=2S-13A Tgt 2 A3 081816 PB 14,700.00 89.88 21.00 6,268.80 6,110.00 4,332.73 -5,195.95 3.50 2,294.32 14,800.00 86.38 21.03 6,272.06 6,113.26 4,426.02 -5,160.12 3.50 2,394.23 14,900.00 82.88 21.05 6,281.41 6,122.61 4,518.93 -5,124.38 3.50 2,493.76 14,902.64 82.79 21.05 6,281.74 6,122.94 4,521.37 -5,123.44 3.50 2,496.38 Start 104.32 hold at 14902.64 MD 15,000.00 82.79 21.05 6,293.95 6,135.15 4,611.52 -5,088.74 0.00 2,592.96 15,006.96 82.79 21.05 6,294.83 6,136.03 4,617.96 -5,086.26 0.00 2,599.86 Start DLS 3.50 TFO-2.43 15,041.51 84.00 21.00 6,298.80 6,140.00 4,649.99 -5,073.95 3.50 2,634.17 Start DLS 3.50 TFO-21.29-2S-13A Tgt 3 A3 081816 PB 15,100.00 85.91 20.25 6,303.94 6,145.14 4,704.52 -5,053.43 3.50 2,692.43 15,200.00 89.17 18.99 6,308.24 6,149.44 4,798.62 -5,019.88 3.50 2,792.32 15,286.92 92.01 17.89 6,307.34 6,148.54 4,881.06 -4,992.39 3.50 2,879.20 Start 1670.39 hold at 15286.92 MD 15,300.00 92.01 17.89 6,306.88 6,148.08 4,893.50 -4,988.38 0.00 2,892.26 15,400.00 92.01 17.89 6,303.38 6,144.58 4,988.61 -4,957.68 0.00 2,992.13 15,500.00 92.01 17.89 6,299.87 6,141.07 5,083.71 -4,926.98 0.00 3,092.00 15,600.00 92.01 17.89 6,296.37 6,137.57 5,178.82 -4,896.28 0.00 3,191.87 15,700.00 92.01 17.89 6,292.87 6,134.07 5,273.92 -4,865.58 0.00 3,291.74 15,800.00 92.01 17.89 6,289.36 6,130.56 5,369.03 -4,834.88 0.00 3,391.61 15,900.00 92.01 17.89 6,285.86 6,127.06 5,464.14 -4,804.18 0.00 3,491.48 16,000.00 92.01 17.89 6,282.35 6,123.55 5,559.24 -4,773.48 0.00 3,591.35 16,100.00 92.01 17.89 6,278.85 6,120.05 5,654.35 -4,742.78 0.00 3,691.22 16,200.00 92.01 17.89 6,275.34 6,116.54 5,749.46 -4,712.08 0.00 3,791.10 16,300.00 92.01 17.89 6,271.84 6,113.04 5,844.56 -4,681.38 0.00 3,890.97 16,400.00 92.01 17.89 6,268.33 6,109.53 5,939.67 -4,650.68 0.00 3,990.84 16,500.00 92.01 17.89 6,264.83 6,106.03 6,034.78 -4,619.98 0.00 4,090.71 16,600.00 92.01 17.89 6,261.32 6,102.52 6,129.88 -4,589.28 0.00 4,190.58 16,700.00 92.01 17.89 6,257.82 6,099.02 6,224.99 -4,558.58 0.00 4,290.45 16,800.00 92.01 17.89 6,254.31 6,095.51 6,320.10 -4,527.88 0.00 4,390.32 16,900.00 92.01 17.89 6,250.81 6,092.01 6,415.20 -4,497.18 0.00 4,490.19 16,957.32 92.01 17.89 6,248.80 6,090.00 6,469.72 -4,479.59 0.00 4,547.43 TD at 16957.32 2S-13A Tgt 4 A3 081816 PB 8/24/2016 2'47 08PM Page 6 COMPASS 5000.1 Build 74 1 • ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-13A Design: 2S-13Awp19 Targets i Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Fasting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) 2S-13A Tgt 2 A3 081816 PB 0.00 0.00 6,268.80 4,329.64 -5,197.14 -plan hits target center -Circle(radius 1,320.00) 2S-13A Tgt 0 7-5/8 081816 PB 0.00 0.00 6,331.80 22.31 -5,928.09 -plan hits target center -Cirde(radius 1,320.00) 2S-13A Tgt 4 A3 081816 PB 0.00 0.00 6,248.80 6,469.72 -4,479.59 -plan hits target center -Cirde(radius 1,320.00) 2S-13ATgt 1 A3 081816 PB 0.00 0.00 6,268.80 3,755.20 -5,347.67 -plan hits target center -Circle(radius 100.00) 2S-13A Tgt 3 A3 081816 PB 0.00 0.00 6,298.80 4,649.99 -5,073.95 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,315.83 6,331.80 7-5/8"x 9-5/8 7-5/8 9-7/8 16,957.32 6,248.80 41/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS pip Direction (usft) (usft) Name Lithology (°) (°) 10,251.59 6,322.80 A3 0.00 9,469.17 6,089.80 U Kalubik 0.00 9,959.86 6,261.80 Kup C(Top C4) 0.00 9,674.73 6,171.80 Kalubik(K-1) 0.00 9,218.63 5,974.80 THRZ 0.00 10,002.77 6,272.80 A4 0.00 8/24/2016 2:4708PM Page 7 COMPASS 5000.1 Build 74 I 41111 ConocoPhillips Standard Proposal Report Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 2S-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Project: Kuparuk River Unit MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad North Reference: True Well: 2S-13 Survey Calculation Method: Minimum Curvature Wellbore: Plan'2S-13A Design: 2S-13Awp19 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment i 9,033.19 5,885.32 -1,063.80 -5,478.30 Start DLS 3.51 TFO 71.48 9,125.00 5,931.30 -998.16 -5,523.07 Start DLS 12.50 TFO-30.00 9,138.00 5,937.56 -988.61 -5,529.28 Start 20.00 hold at 9138.00 MD 9,158.00 5,946.98 -973.89 -5,539.01 Start DLS 3.00 TFO-30.00 9,218.00 5,974.52 -929.69 -5,568.80 Start DLS 3.00 TFO-165.09 9,283.67 6,004.83 -881.83 -5,602.01 Start 32.76 hold at 9283.67 MD 9,316.42 6,020.43 -858.25 -5,618.55 Start DLS 3.50 TFO 58.58 10,315.83 6,331.80 22.31 -5,928.09 Start 20.00 hold at 10315.83 MD 10,335.83 6,334.35 42.06 -5,929.99 Start DLS 3.50 TFO 60.48 10,844.81 6,359.80 547.97 -5,910.09 Start 3192.74 hold at 10844.81 MD 14,037.55 6,269.71 3,691.47 -5,358.87 Start DLS 2.50 TFO 178.08 14,102.26 6,268.80 3,755.20 -5,347.67 Start DLS 2.50 TFO 90.00 14,266.87 6,268.80 3,916.14 -5,313.29 Start 233.11 hold at 14266.87 MD 14,499.98 6,268.80 4,142.21 -5,256.44 Start DLS 3.50 TFO 90.00 14,696.69 6,268.80 4,329.64 -5,197.14 Start DLS 3.50 TFO 179.59 14,902.64 6,281.74 4,521.37 -5,123.44 Start 104.32 hold at 14902.64 MD 15,006.96 6,294.83 4,617.96 -5,086.26 Start DLS 3.50 TFO-2.43 15,041.51 6,298.80 4,649.99 -5,073.95 Start DLS 3.50 TFO-21.29 15,286.92 6,307.34 4,881.06 -4,992.39 Start 1670.39 hold at 15286.92 MD 16,957.32 6,248.80 6,469.72 -4,479.59 TD at 16957.32 8/24/2016 2408PM Page 8 COMPASS 5000.1 Build 74 AC Report • 0 NCL a m N I c 0 • Ec a 01 C m N Ny 22 N N N fl O U N p 00••••• t2 W pNp CtS w xo co o d� 2 p C/) r C w o V� o o }� ? t%1 0 E N Ca N N G w C � O R Q 7 o = m N EW i y v a2 w fl 3 . Wv0a3 i N d 3 O U QH _= pinZLii- E ilm • y=mum C/) O t6 tv N Q U LL Z Q CO• li = \V V+ E v CO CI cfl = N 1:1- L O .O 'a. 0�1� r O M Q n J N Q Q _ m < � � C � T d 3 01 r r � a '+ Y o o V R N N T (0 0 N f c N `6 °k°_ m m 2 0 ti ay Z Tma oT. t C5 i L N N Q as ■— 7 a 0 c ai 0 o M }1 8) c w o .13 3 rn ui &; O Q. a. r c TO r Q U m U c a o cT ca V Y Y N a LO N 0 Q w - ill N � � � � �n u� C7 > cc'', n in 3 I • N C. co 4 rn S O <.3 - E O r �.. = C Y Y Y Y Y Y Y Y Y Y 1. C N N .5.4. N N N N N N - N N 'i CC CC CCr CLCL CL' Q'Cr r CLCC et co a 03 8 O O O O O O O O O N h nml aaaa_ CO CO AO c U a = N7 iiii! mEZ..0 LL N E C C 111111 0 0E m i c u, u?W ccs co 1- N N U m 0 0 0 0 r) r) o (0 0 0 1 ( cO Y Y Y m o m o Cl) U (A Q Q < < Q 0) 0) o (0 r N N Cr U LL LL CC LL LL_ v A 0 + + F + + co co 2 LL 1 600 + 000o 00 0 0 . . . 0 0 a o 0 0 : _ 0 . 0 . Q . L 00) 0) N 07 N (00 O N Or N N G 0 1 O O Y c CO CO ro m � � ao of C 1:1i ti M CO o ai 1.m q ri (o r N ` -6 V Cr m CO N W N y 4- r O) 0) 'O N O M Of O) O )0 (0 (0 N uN• 0) (O N ae, a' M M (0 .:7. M V C L E O co O O N O 7 Csi 1 (0 N E C lIiiiIIi,(00 o N N: M O E a coOOIW O o co co s s ai g CO a CO N N 0) CO A W A O 0) O7 17 U coOi r 0 V M M M O M M 3, N 3CL CL CL d CL a L W N = O O O V7 e O NOr) M M M M M �' °' co 2 ii jrI Q l ,- al 2 � � � cncn N N N N N M L M y 0 O r 1 ? N E CO V CO 0 0 0 0 N Cl) C O O O O O O M N m2 Q 0 0) r--: m on ° CO o rn 1 0 - L N y N r O M M M W � Q. C .... N 0) 0) O O (fl d (0 N M r.. N O o .CO CO CO N y C) O Q a " 0 3 3 Cl) c a 3 c N ` . N CC y J J Mw R E E 0) co Cl) 0 0 0 0 L 7 1L (0 R N K) 0 0 0 0 0 U) w Z CO U) N Cal L 0 O Cn 0 C] O (O cO U (n r M O O {~ C N W ` L 0 O N M N O V' V M M 4-i C a .o N di '• LL `C.. N CA CP CA O O L N R N N _ _ _ c c .-- 0 O COLL `) _a) d m Cb CO 6 ~O 0 N //�� r Uri CL wa. .' N • • N J J CO co CO CO O W E " N ,- co r e- 'O a i ` N Ech M l0 r W is N CO CO c u) N N J J V V 41 (0 `O 2 O 6 M 2co N N CO L Y y Q. N m N ch N m m <, N CO .Z N O (y 3 (n 0_ J J CL CL N N � (/) C !') (N N CO CO CO CO 0) •(f) O C( O ' C N c c Co Z 'N of N d °y .. O) 6 6 V) V) (/) (n u) t0 l0 C0 (n y d E = N N N N N N N N d 0- N N Q c a 0 N 7 R CO R Cr C U C a 2 Q N N CO CO CO CO CO CO CO CO a 7 'T C C Ca w 3 r . ' )- N- N- r r id U d Cr CC O c u) N !n U) 6 6 6 6 u) 6 6 • y C C Cl) 0 Y N (N N N N N N N N N N N Q I` N co (b) F � N y • • N O. C Co Co CC Q ( G) g - 0 c.; n! E 0 '-' et = c 0 0 0 0 0 0 � c O N N N N N N Cl.cA ° C N 0 0 O O O O Q C C CC _ C .. _ (0 CC G il 0 0 c4 0 0fA E !IJP!! N 7 u U `U U U O C co U m 2.•2 r. Co LL +R.' LL. co .4. E o III - O O F N N N N 0 Y Y 0 0 0 0 0 0 0 0 3 (n Q Q p Q Q d O O o o N CO o U lL lL lLlL CO LL 6 0 O + 0 0 0 CO T 0 U 0 0 0 0 a 0 0 0 0 o 0 0 0 o L 0 o 0 0 .. m m c O O w W W- (I) o Ibni 0.. 0._0lai La La Lct lit' a (q00 IIIoo; y y = U c c _ m w c •C Co .a O m ❑ m ca al O. O' cn d a N 01 O) O) O) W Co U wO. a^ 7 CC fCO Q Q Q Q Q Q vi Q ` m Q Q Q Q Q d W W m 7 w 0 k a) Cl ..- M M CO M M C rq O o 42 Q re L Q a N N N N N Co p 'Co o c • Z N £ W V 6) O O O O N N 3 Co CU Cl) (p C 0 0 0 0 0 0 CO C m N.: � ° O o a c ? CocD V f6 Q CIU) y O y N I, O V M M M O CC mU Co Q0> N - dCM LO 81 N Nco E r co C [=7 a) O U1 0 o C_ N c l a w U 7, N Z E' ` U CCa Q L N r) E m CD 01 0 0 0 0 41 v 'o is L (7 W LL Co O N N .- 0 0 0 0 j Q 1) Co• .= I as 0 C N Co U ` 01 I- c�1 l0 lA N N O ' R O O O N co,, CO 0 V V CO 0 N N O L R R ''�-' (0 lL 7 - N W Q) O O O O o 'L N d r t n d U N U O Ya O 0 N N ("� Q. CL. O a N N U (C <O i.f. M • J J ,1.I Co UC 'L" Co U CD Y t Co M co 7 7 CoCo /e/ X 10 0 N E m CO m COy CoU m LL x !a 0 O Co a M CO CO (� N N N O O y N N o O` O. l0 N Z N N a s U1 d 7 co CC (n !n U O N 2 i ON Y O o0 W O. N N [O co .7 N U C N 0 t' r J J 0_ 0_ U p C O M Ih M (`') M M CoO N Co U II (6 CO •(� O 0 0 N C N N O N N 01 owl • Z y O N 0 y Y 6 (A 6 6 6 6 E Q. w N V . Q y 0 • 3 NNNNNN 15- ei `O mill O 7 R 10 �' N N N lL O ,o- (NI 4 C C a Z O. a 0 0 0 0 0 0 -O c0 m N > A !0 I P. O U ("� N U Y N N N N N N N C N t,I C � C0U aCCN � y Q F re v1 y W 0 U 0 0 0 \ ® � � m ) R / co g / \ \ � U 0 \ co3 £ e . ' � k 7 \ | CI) ) a) ƒ CNI a. k co } • m e cel _ % £ CO •. o 33 d \ ƒ Cs1 a) 2 - o = - o d, / 0. 7 ) \ c � © 12g- 11 E Q _ 1.71 & § 8 c1 � E a E • { ) \ 0 ° \ \ ^ _ - « w o w o o < 4/11 • 11:25, August 24 2016 2S-13Aw 19 Ladder View pThe Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors m 300 I J, ,h N// — / N Q111 CO J 2 150 I ®� m IlL' 111 ' 4111111011h"116..w- ®yl ► U — Equivelant MagneticDistance "►.�,— .. _ ._. .. .. :. I i' '°° iI 0 r i i ( 1 f 1 1 1 T Fr I ( 1 1 1 1 i I 1 1 9000 10500 12000 13500 15000 16500 18000 Displayed interval could be less than entire well:Measured Depth9033.19 To 16957.32 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 94.18 1295.08 25-13PB1 Srvy#1 -SLB_NSG+Ba *611g4$S-13PB1) 63311E015.83 7-5/8"x 9-5/8" 1316.29 2787.04 2S-13PB1 Srvy#2-SLB_MWD+GMl90199BFt1-291142 r}1Z-SC 6248'I P57.32 4 1/2"x 6-3/4" 2879.51 9033.19 2S-13PB1 Srvy#3-SLB_MWD+GMW -2BR1- )1Z-SC 9033.19 9450.00 2S-13Awp19 (Plan: 25-13A) INC+TREND 9450.0010316.00 2S-13Awp19 (Plan: 2S-13A) MWD 9450.0010316.00 2S-13Awp19 (Plan: 2S-13A) MWD+IFR-AK-CAZ-SC 10316.0011300.00 2S-13Awp19 (Plan: 2S-13A) MWD 10316 0016957.32 2S-13Awo19 (Plan- 2S-13A1 MWD+IFR-AK-CA7-SC m N a N N N 60 Q co N 30 I I!U C Equiverm Magnetic Distance U i 0 i i f I I I I I I 1 I I I 1 I I I I I 1 I 1 5 9000 9200 9400 9600 9800 10000 10200 Partial Measured Depth Inc TVD +3.0 +E/-W D.00 TFace. ect Target `9033 `J`,13L 9033. .42 323.94 5885.32 -1063.80 -5478.30 0.00 0.00 33 25-13Awp19 9125.0 0.49 327.45 5931.30 -998.16 -5523.07 3.51 71.48 - 6.96 9932 10112 9138.00 61.90 326.53 5937.56 -988.61 -5529.28 12.50 -30.00 -2820.11 9033.19 To 16957.32 9158.00 61.90 326.53 5946.98 -973.89 -5539.01 0.00 0.00 -2809.61 10112 10302 9218.00 63.46 325.52 5974.52 -929.69 -5568.80 3.00 -30.00 -2778.26 9283.67 61.56 324.95 6004.83 -881.83 -5602.01 3.00 -165.09 -2744.65 9316.42 61.56 324.95 6020.43 -858.25 -5618.55 0.00 0.00 -2728.15 10302 10482 10315.83 82.68 354.50 6331.80 22.31 -5928.09 3.50 58.58 -2006.56 2S-13A Tgt 0 7-5/8 081816 PB 11:29.August 24 2016 10335.83 82.68 354.50 6334.35 42.06 -5929.99 0.00 0.00 -1988.66 10482 10662 10844.81 91.62 9.95 6359.80 547.97 -5910.09 3.50 60.48 -1506.45 14037.55 91.62 9.95 6269.71 3691.47 -5358.87 0.00 0.00 1636.00 10662 - 10852 SURVEY PROGRAM 14102.26 90.00 10.00 6268.80 3755.20 -5347.67 2.50 178.08 1699.72 2S-13A Tgt 1 A3 081816 PB ee Prem Deem ro survglPlan Tool 14266.87 90,00 14.12 6268.80 3916.14 -5313.29 2.50 90.00 1862.72 94.18 1295.08 2S-13P81Srvy Al-SLBNSOaID10006.8(2e.13P91) 14499.98 90.00 14.12 6268.80 4142.21 -5256.44 0.00 0.00 2094.60 10852 11032 1318.29 2787.04 26-13Pe1 Srvy182-SLB_MWIMAIIMAEMRIMMABBC 2879.51 9033.19 2S-13Pe1 Sr,x3-SLB_MN990.1.66.2003AISMC 14696.69 90.00 21.00 6268.80 4329.64 -5197.14 3.50 90.00 2291.01 2S-13A Tgt 2 A3 081816 PB 9033.19 9450.00 2S-13Awy19(Plan:2S-13A)INOATREND 14902.64 82.79 21.05 6281.74 4521.37 -5123.44 3.50 179.59 2496.38 11032 ---- 11212 9450.00 10316.00 26.13Av 019(Plan:2S-13A)MND 9450.00 10316.00 26-13Awp19(Plan)2S-13A)MWDRPR-A-CAzsC 15006.96 82.79 21.05 6294.83 4617.96 -5066.26 0.00 0.00 2599.66 10316.00 11300.00 25-13.819(Plan(2S-13A)MWD 15041.51 84.00 21.00 6298.80 4649.99 -5073.95 3.50 -2.43 2634.17 2S-13A Tgt 3 A3 081816 PB 11212 11452 1oa Aw s.90 16951.32 25-13p191P1an(22.-13A)M'NMIFR-AK-0A25D 15286.92 92.01 17.89 6307.34 4881.06 -4992.39 3.50 -21.29 2879.20 CASING DETAILS 16957.32 92.01 17.89 6248.80 6469.72 -4479.59 0.00 0.00 4547.43 2S-13ATgt 4A3 081816 PB 11452 11692 TVD MD Name Size 11692 11922 6331.80 10315.83 7-5/8"x 9-5/8" 7-5/8 6248.80 16957.32 4 1/2"x 6-3/4" 4-1/2 11922 12162 12162 --- 12402 12402 12632 0/360 12632 12872 12872 -"-"' 13112 __ �� 0\ \� 13112 13582 -30/330 21 ?; 4Nt�, 30 13582 14052 __.....--mmolso#F. --1-1 k2.. ,k-: ,,., 14052 - 14522 ..tN'1414V\ �j I'''4i�;' 's 14522 14992 --,11°,1%,„0:4054,44',-etiVO• 14992 u� 15472 5 �, 4,, ',41te .'64:1®0 15472 15942 / j ®T :���1 °` ��1��� a�i°t ��'' ��-�A\���� 15942 16412 -60/300 i /� / at< 4t�p ►. .,,? 60 16412 16879 �� i--I 7� 4' s+k�l[��-R' '�,� c altar 4 �/ •//' // // / %' / /,/i / 1 ,.�w� ,4% „w s ".` 7✓,,., ;' ///////i/p/ ' /./.7 i / �" I �1 # I_ r4 t tw i. /////// .4 i., --///41 *44410./:. '-'I'4'1,n**1::'''' . \''.1\V"0.4t., § / i l' 1 - , / „.Jo, .c,..8 alk.. "'pi:fry , It 4/0,0,,4,4* ‘1/004446, 7 ii 7 It , ,, ii j," roc!, r.44:404(;;;9,„:44,111,::, 30 I/( // 7 1 i i: 7 // 1 4.• .4,41PicorA . t.' ,,,'',4it A , 4 03...,.,....41/4 -90/270- F ',\ik, 1,c, , i 14r:0A- ifI, t.-' giik,,..t..r 1 8„9., ; I� I ►r•f T},Zi-� 90 „ ,4, „I' , , 1' \',: \ ' ' ‘V\ti, il ',';. 01100,i pi , ELTATIO,,,.. ia „1,,,, ' ' ‘1‘'IN'- ,4 / Ift VAC \\ t of/iit'l ./.p it , krr . ,k4::;', , I, . /-i it. ,i';yiricrittlrt,.. \ .♦ ♦' vl0'4 1���tppp��� i i �/14 ,7 \ - 'per 1,4/0A4y \V,\ Nik Nitlitri- iittiS,0,41,\''‘' '!:‘,>.,,"„et,„.....A/Att\\) I''Y'',4;'''. 1 - 1 N,.._...,NN,, ,,,,04.,;•P' Axlc‘-‘33747:11114\tiV: \'t1"/":7":". :' *7/i1X1 081* ' IV -120/240 - +�-.401 .49046111:��� � 5 .� s � ��1® �@e V /s 120 : ...-may v" @7• : ,11111 . . .\1.=--_ =.rai-tea-- .v.. 4,4 " ;t,;-...,,1.-.. ' 11tIV �`Ai# \ '� .6;�4 '� ' �1e� \ ®\``'` _�. - r2& j ,,-_ .- .:g .44114400006.. 7a 150/2101. / 150 J -180/180 2S-13PB1I -� 22.13.2&13.12-13V2 % 25_14.22-Itt 2s,xlva j(- 22.12.zsIaae,.3s12P51 vo $ 2s1xe19 Inc Azi TVD +N/-S +FJ-W Dleg TFace eel Target `JU33 6.i`.i3L 9033. .42 323.94 5885.32 -1063.80 -5478.30 0.00 0.00 .33 2S-13Awp19 9125.0 0.49 327.45 5931.30998.16 5523.07 3.51 71.48 6.96 9932 10112 9138.00 61.90 326.53 5937.56 -988.61 -5529.28 12.50 -30.00 -2820.11 9033.19 To 16957.32 9158.00 61.90 326.53 5946.98 -973.89 -5539.01 0.00 0.00 -2809.61 10112 10302 9218.00 63.46 325.52 5974.52 -929.69 -5568.80 3.00 -30.00 -2778.26 9283.67 61.56 324.95 6004.83 -881.83 -5602.01 3.00 -165.09 -274465 9316.42 61.56 324.95 6020.43 -858.25 -5618.55 0.00 0.00 -2728.15 10302 10482 10315.83 82.68 354.50 6331.80 22.31 -5928.09 3.50 58.58 -2006.56 2S-13A Tgt 0 7-5/8 081816 PB 16:01,August 24 2016 10335.83 82.68 354.50 6334.35 42.06 -5929.99 0.00 0.00 -1988.66 10482 10662 10844.81 91.62 9.95 6359.80 547.97 -5910.09 3.50 60.48 -1506.45 14037.55 91.62 9.95 6269.71 3691.47 -5358.87 0.00 0.00 1636.00 10662 10852 SURVEY FRODRAAI 14102.26 90.00 10.00 6268.80 3755.20 -5347.67 2.50 178.08 1699.72 2S-13A Tgt 1 A3 081816 PB •Po.9From 6.18 ,ms.os zs-i3nrr'r, xt-sLe_Nsmmmgs�9lzs-13Pe11 14266.87 90.00 14.12 6268.80 3916.14 -5313.29 2.50 90.00 1862.72 1316.29 2787.06 2S-13P511 Srvy02-SLB_M1ONMM619180mrmeaC 14499.98 90.00 14.12 6268.80 4142.21 -5256.44 0.00 0.00 2094.60 10852 11032 2979.51 9033.19 25-131.e15,03-SIR_MW1511939117(396GRARC 14696.69 90.00 21.00 6268.80 4329.64 -5197.14 3.50 90.00 2291.01 2S-13A Tgt 2 A3 081816 PB 9033.19 9650.00 25.13A,19(Plan(25.136)INC6TREND 14902.64 82.79 21.05 6281.74 4521.37 -5123.44 3.50 179.59 2496.38 11032 11212 9650.00 10316.00 25.13Awn19(Plan:213A)MWD 9650.00 10316.00 25-13AwP19(Plan:25-S-13A)MWDHFR-AKLPZSC 15006.96 82.79 21.05 6294.83 4617.96 -5086.26 0.00 0.00 2599.86 10318.00 1/300.93 25-13.919(Plan:25-13A)MWD Awp15041.51 84.00 21.00 6298.80 4649.99 -5073.95 3.50 -2.43 2634.17 2S-13A Tgt 3 A3 081816 PB 11212 11452 10316.00 18957.32 25-13191P1an:25-13A)MWM -A IFRKLAZSL 15286.92 92.01 17.89 6307.34 4881.06 -4992.39 3.50 -21.29 2879.20 CASING DETAILS 16957.32 92.01 17.89 6248.80 6469.72 -4479.59 0.00 0.00 4547.43 26-13A Tgt 4 A3 081816 PB 11452 11692 TVD MD Name Size 11692 11922 6331.80 10315.83 7-5/8"x 9-5/8" 7-5/8 8248.80 16957.32 41/2"x6-3/4" 4-1/2 11922 12162 12162 12402 12402 12632 12632 12872 0/360 12872 13112 225 13112 13582 -30/330 210 30 13582 _-- 14052 195 14052 14522 186 14522 14992 165 14992 15472 :: 151 15472 15942 1. 15942 16412 60/300 12I 60 16412 " 16879 10 90 61 L,v 1, 4 2" / J \ - ..• _ - �' -4.41 A t / y\ t3:F F� '# Y:„1 6 -90/270 a 90 45 �t : r 60 -; 90 12s-131 105 -120/240 120 120 135 "'aa9 150 1;, 165 180 195 11-42 -150/210 210 150 225 ,•70 -180/180 12S-13PB1 -X- 731325.131.61.=3-1.131V0 t 2s132.111.:5-131.1V0 -tt- 3s13.25-13.:s13V0 $ m d • • Northing (2500 usft/in) IiiiilmilliiiilliiiilmiliiiiiiiiiliiiiiiiiiIiiiiliiiilliiiiiiiiIiiiiIii - 0 d) - N — 00 _ - a 3 - rn - o - N Z3 CO — ad J O _ _ O 11-.•. 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Ol O O O O O 0 - N N N N rn M Cr" Cr Ct' Ln dam\ '� kD a r r r r c-- r r r r r r r r r r r r r r r r r r i N'\ N N N N N N N N N N N N N N N N N N N N N N N rn M r- 0 00 �0 L' M r" Ln 61 N 1/4.00 rn f-,-. r' 00 LJ\ N 01 N. d- _, O 61 O r d- 'o co o iN CI- 61 r- Cr 1/4.0 00 1 Lf\ 0 L.n 0- C1" a '- 61 61 r 0 0 0 0 r r r r r N N N N r rn d" d" d- L/\ LI\ r r r r �-- r r r r r r r r r r r r- r r- 0 O 55 < < O N aao a a r §iW i U LL LL C - + uoo� oo 0 33-3333 mN a ry V V O m O \ Ll1ou3�. aaaaa Z ���NNrNr f if3"au.aaa `� `. o m v m....r+ moo-0000�• '\ '` O E°0 n .. 0 O O ....— � 00 u`.m'O Amo o�� _.._..._• m?o11mm M a I rn 0 COr- L E lir ,I,' z o o \ m \ - O fM N M Lf1 N M o ___. ___r_r___________--- o o P. rr) N Lr\ ,_ 0 1/4o O. N 0N et- o I i c- N /0 L vi N Ci- in rn rn N in in 0 0 in Ln 0 r�1'�l N a L!1 Ln a L01 t01 M a 'Cr Ln Ln Ln O1 61 in in C 61 0 r o 0 0 0 00 00 b= 0 rn f� k0 Ln d- d- d- d- 61 61 O �' _- r r r N. f\ Q N N N N N N N Ln Lf\ r N N N N r- r I 0 r rn rn rn rn rn rn rn rn n • M N 0 Q d1 0 0 0 0 n N rn rn r' Vl L0 N. 00 61 d' L0 r NN e� 0 0 0 0 0 ' d- 00 00 O Ln N CO 6-, '.o 'o Ern Ln Ern in 0 MN000000 � 1- m � M00 rnrn0 0 0CC "" 0 r r r N N rn M rn 00 0 r N d- qp 61 0 En N 61 Cr 61 61 61 01 61 ON 61 0 0 0 Cr Ci- C1- d- d- d Ln r Ln r r r r r r r r r' r r r Errors Report • • ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2S Pad 2S-13 501032072000 Plan: 2S-13A Plan: 2S-13Awp19 Error Ellipse Survey Report 24 August, 2016 To s: Multiply by 2.58 i 0 Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp19 Output errors are at 1.00 sigma Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: 5,929,785.73 usft Latitude: 70°13'10.937 N From: Map Easting: 1,621,342.25 usft Longitude: 150°9'13.991 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well 2S-13 Well Position +N/-S 0.00 usft Northing: 5,929,698.39 usft Latitude: 70°13'10.068 N +E/-W 0.00 usft Easting: 1,620,931.42 usft Longitude: 150°9'25.916 W Position Uncertainty 0.00 usft Wellhead Elevation: 119.40 usft Ground Level: 119.80 usft Wellbore Plan 2S-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2016 11/30/2016 17.71 80.84 57,531 Design 2S-13Awp19 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,033.19 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 20.00 Survey Tool Program Date 8/24/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 94.18 1,295.08 2S-13PB1 Srvy#1-SLB_NSG+Battery+S GYD-GC-SS Gyrodata gyro single shots 1,316.29 2,787.04 2S-13PB1 Srvy#2-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,879.51 9,033.19 2S-13PB1 Srvy#3-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,033.19 9,450.00 2S-13Awp19(Plan:2S-13A) INC+TREND Inclinometer+known azi trend 9,450.00 10,316.00 2S-13Awp19(Plan:2S-13A) MWD MWD-Standard 9,450.00 10,316.00 25-13Awp19(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,316.00 11,300.00 2S-13Awp19(Plan:2S-13A) MWD MWD-Standard 10,316.00 16,957.32 2S-13Awp19(Plan:2S-13A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°I (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 9,100.00 60.19 326.50 5,918.93 15.88 -2.23 18.06 -4.22 8.67 4.07 6.43 28.69 12.24 87.28 INC+TREND(1,4) 9,125.00 60.49 327.45 5,931.30 15.87 -2.29 24.16 -4.27 8.69 4.09 6.45 30.27 18.01 98.91 INC+TREND(1,4) 9,138.00 61.90 326.53 5,937.56 15.40 -2.36 28.13 -4.22 8.70 4.10 6.46 31.96 20.43 108.44 INC+TREND(1,4) 9,158.00 61.90 326.53 5,946.98 15.41 -2.36 34.32 -4.22 8.72 4.11 6.48 36.16 22.75 122.62 1NC+TREND(1,4) 8/24/2016 11:40.19AM Page 2 COMPASS 5000.1 Build 74 i • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp19 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°1 9,200.00 62.99 325.82 5,966.41 15.10 -2.42 48.12 -4.19 8.79 4.14 6.52 48.58 24.43 136.74 INC*TREND(1,4) 9,218.00 63.46 325.52 5,974.52 14.98 -2.44 54.21 -4.18 8.82 4.15 6.53 54.48 24.68 139.15 INC+TREND(1,4) 9,218.63 63.44 325.52 5,974.80 14.98 -2.44 54.21 -4.18 8.82 4.15 6.53 54.48 24.68 139.15 INC+TREND(1,4) 9,283.67 61.56 324.95 6,004.83 15.59 -2.28 76.54 -4.15 8.95 4.19 6.60 76.59 25.03 142.79 INC+TREND(1,4) 9,300.00 61.56 324.95 6,012.61 15.62 -2.28 82.09 -4.15 8.99 4.20 6.61 82.12 25.07 143.18 INC+TREND(1,4) 9,316.42 61.56 324.95 6,020.43 15.65 -2.28 87.68 -4.15 9.03 4.21 6.63 87.70 25.10 143.48 INC+TREND(1,4) 9,400.00 63.11 327.75 6,059.23 15.67 -2.50 116.28 -4.29 9.34 4.27 6.71 116.44 25.27 144.70 INC+TREND(1,4) 9,469.17 64.44 330.00 6,089.80 16.01 -2.75 133.21 -4.62 9.53 4.33 6.91 133.86 25.35 145.24 MWD(1,5) 9,500.00 65.04 330.99 6,102.96 16.01 -2.75 133.21 -4.62 9.53 4.33 6.91 133.86 25.35 145.24 MWD(1,5) 9,600.00 67.04 334.14 6,143.57 16.46 -3.01 132.36 -5.11 9.54 4.38 7.22 133.93 25.26 145.19 MIND(1,5) 9,674.73 68.57 336.43 6,171.80 16.91 -3.26 131.18 -5.58 9.56 4.43 7.53 134.03 25.14 145.14 MWD(1,5) 9,700.00 69.10 337.19 6,180.93 18.91 -3.28 131.18 -5.58 9.56 4.43 7.53 134.03 25.14 145.14 MWD(1,5) 9,800.00 71.21 340.16 6,214.88 17.18 -3.50 129.70 -6.02 9.59 4.47 7.84 134.15 24.99 145.10 MIND(1,5) 9,900.00 73.36 343.06 6,245.32 17.16 -3.72 127.94 -6.44 9.64 4.51 8.13 134.28 24.81 145.06 MWD(1,5) 9,959.86 74.67 344.76 6,261.80 16.80 -3.93 125.93 -6.83 9.69 4.54 8.41 134.42 24.60 145.04 MIND(1,5) 10,000.00 75.56 345.89 6,272.11 16.80 -3.93 125.93 -6.83 9.69 4.54 8.41 134.42 24.60 145.04 MWD(1,5) 10,002.77 75.62 345.96 6,272.80 16.10 -4.12 123.68 -7.19 9.76 4.57 8.67 134.58 24.38 145.02 MIND(1,5) 10,100.00 77.79 348.66 6,295.17 16.10 -4.12 123.68 -7.19 9.76 4.57 8.67 134.58 24.38 145.02 MWD(1,5) 10,200.00 80.04 351.39 6,314.40 15.08 -4.28 121.21 -7.52 9.84 4.59 8.92 134.76 24.13 145.02 MIND(1,5) 10,251.59 81.21 352.78 6,322.80 13.81 -4.41 118.53 -7.82 9.94 4.60 9.14 134.94 23.89 145.02 MWD(1,5) 10,300.00 82.32 354.08 6,329.73 13.81 -4.41 118.53 -7.82 9.94 4.60 9.14 134.94 23.89 145.02 MWD(1,5) 10,315.83 82.68 354.50 6,331.80 13.59 -4.43 118.09 -7.86 9.96 4.60 9.17 134.98 23.85 145.02 MIND(2,6) 10,335.83 82.68 354.50 6,334.35 13.31 -4.35 117.53 -5.40 9.61 4.61 7.29 134.10 24.86 145.16 MIND(2,6) 10,400.00 83.79 356.47 6,341.91 12.67 -4.42 115.31 -5.59 9.62 4.62 7.42 134.15 24.63 145.14 MIND(2,6) 10,500.00 85.54 359.51 6,351.21 11.58 -4.50 111.62 -5.86 9.63 4.62 7.59 134.25 24.27 145.12 MIND(2,6) 10,600.00 87.29 2.55 6,357.47 10.56 -4.57 107.66 -6.09 9.66 4.63 7.73 134.35 23.90 145.11 MIND(2,6) 10,700.00 89.06 5.57 6,360.65 9.86 -4.62 103.45 -6.28 9.71 4.63 7.85 134.45 23.54 145.12 MWD(2,6) 10,800.00 90.83 8.59 6,360.75 9.83 -4.64 98.97 -6.43 9.77 4.63 7.95 134.57 23.20 145.13 MWD(2,6) 10,844.81 91.62 9.95 6,359.80 10.10 -4.65 96.89 -6.48 9.80 4.63 7.98 134.62 23.06 145.14 MWD(2,6) 10,900.00 91.62 9.95 6,358.24 10.14 -4.65 96.94 -6.52 9.84 4.63 8.02 134.68 22.88 145.16 MWD(2,6) 11,000.00 91.62 9.95 6,355.42 10.23 -4.65 97.02 -6.60 9.92 4.63 8.09 134.80 22.55 145.18 MWD(2,6) 11,100.00 91.62 9.95 6,352.60 10.32 -4.65 97.12 -6.68 10.02 4.63 8.16 134.92 22.27 145.21 MIND(2,6) 11,200.00 91.62 9.95 6,349.78 10.43 -4.65 97.24 -6.75 10.13 4.62 8.23 135.05 22.03 145.25 MIND(2,6) 11,300.00 91.62 9.95 6,346.95 10.08 -4.65 96.81 -5.69 9.77 4.62 7.40 134.36 23.79 145.15 MWD+IFR-AK-CAZ-SC(3,6) 11,400.00 91.62 9.95 6,344.13 10.11 -4.65 96.83 -5.69 9.80 4.62 7.41 134.39 23.69 145.16 MWD+IFR-AK-CAZ-SC(3,6) 11,500.00 91.62 9.95 6,341.31 10.14 -4.65 96.85 -5.69 9.84 4.62 7.42 134.42 23.60 145.17 MWD+IFR-AK-CAZ-SC(3,6) 11,600.00 91.62 9.95 6,338.49 10.18 -4.65 96.87 -5.69 9.88 4.62 7.44 134.45 23.51 145.17 MWD+IFR-AK-CAZ-SC(3,6) 11,700.00 91.62 9.95 6,335.67 10.22 -4.65 96.90 -5.69 9.92 4.61 7.45 134.48 23.43 145.18 MWD+IFR-AK-CAZ-5C(3,6) 11,800.00 91.62 9.95 6,332.85 10.27 -4.65 96.93 -5.69 9.97 4.61 7.46 134.52 23.38 145.19 MWD+IFR-AK-CAZ-5C(3,6) 11,900.00 91.62 9.95 6,330.03 10.32 -4.65 96.97 -5.69 10.02 4.61 7.48 134.56 23.30 145.20 MWD+IFR-AK-CAZ-SC(3,6) 12,000.00 91.62 9.95 6,327.20 10.37 -4.65 97.01 -5.69 10.07 4.61 7.49 134.59 23.24 145.21 MWD+IFR-AK-CAZ-SC(3,6) 12,100.00 91.62 9.95 6,324.38 10.42 -4.65 97.05 -5.69 10.12 4.60 7.51 134.63 23.19 145.23 MWD+IFR-AK-CAZ-SC(3,6) 12,200.00 91.62 9.95 6,321.56 10.48 -4.65 97.09 -5.69 10.18 4.60 7.52 134.67 23.15 145.24 MWD+IFR-AK-CAZ-SC(3,6) 12,300.00 91.62 9.95 6,318.74 10.53 -4.65 97.14 -5.69 10.24 4.60 7.54 134.72 23.11 145.25 MWD+IFR-AK-CAZ-SC(3,6) 12,400.00 91.62 9.95 6,315.92 10.60 -4.65 97.19 -5.69 10.30 4.60 7.56 134.76 23.08 145.27 MWD+IFR-AK-CAZ-SC(3,6) 12,500.00 91.62 9.95 6,313.10 10.66 -4.65 97.25 -5.69 10.37 4.59 7.58 134.80 23.06 145.29 MWD+IFR-AK-CAZ-SC(3,6) 12,600.00 91.62 9.95 6,310.27 10.73 -4.65 97.31 -5.69 10.44 4.59 7.60 134.85 23.04 145.31 MWD+IFR-AK-CAZ-5C(3,6) 12,700.00 91.62 9.95 6,307.45 10.80 -4.65 97.37 -5.69 10.51 4.59 7.62 134.89 23.03 145.32 MWD+IFR-AK-CAZ-SC(3,6) 12,800.00 91.62 9.95 6,304.63 10.87 -4.65 97.43 -5.69 10.58 4.59 7.64 134.94 23.03 145.34 MWD+IFR-AK-CAZ-SC(3,6) 12,900.00 91.62 9.95 6,301.81 10.94 -4.65 97.50 -5.69 10.66 4.59 7.66 134.99 23.04 145.37 MIND+IFR-AK-CAZ-SC(3,6) 13,000.00 91.62 9.95 6,298.99 11.02 -4.65 97.57 -5.69 10.74 4.58 7.69 135.04 23.05 145.39 MWD+IFR-AK-CAZ-SC(3,6) 13,100.00 91.62 9.95 6,296.17 11.10 -4.65 97.65 -5,69 10.82 4.58 7.71 135.09 23.07 145.41 MWD+IFR-AK-CAZ-SC(3,6) 13,200.00 91.62 9.95 6,293.35 11.18 -4.65 97.73 -5.69 10.90 4.58 7.73 135.15 23.10 145.44 MWD+IFR-AK-CAZ-SC(3,6) 13,300.00 91.62 9.95 6,290.52 11.26 -4.65 97.81 -5.69 10.99 4.58 7.76 135.20 23.13 145.46 MWD+1FR-AK-CAZ-SC(3,6) 8/24/2016 11:40.19AM Page 3 COMPASS 5000.1 Build 74 • • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan:119.8+39(Doyon 142)@ 158.8ousft Site: Kuparuk 2S Pad MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp19 Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) ll 13,400.00 91.62 9.95 6,287.70 11.35 -4.65 97.90 -5.69 11.08 4.57 7.78 135.26 23.17 145.49 MWD+IFR-AK-CAZ-SC(3,6) 13,500.00 91.62 9.95 6,284.88 11.44 -4.65 97.98 -5.69 11.17 4.57 7.81 135.31 23.22 145.52 MWD+IFR-AK-CAZ-SC(3,6) 13,600.00 91.62 9.95 6,282.06 11.53 -4.65 98.08 -5.69 11.26 4.57 7.84 135.37 23.27 145.54 MWD+IFR-AK-CAZ-SC(3,6) 13,700.00 91.62 9.95 6,279.24 11.62 -4.65 98.17 -5.69 11.35 4.57 7.86 135.43 23.34 145.57 MWD+IFR-AK-CAZ-SC(3,6) 13,800.00 91.62 9.95 6,276.42 11.71 -4.65 98.27 -5.69 11.45 4.57 7.89 135.49 23.40 145.60 MWD+IFR-AK-CAZ-SC(3,6) 13,900.00 91.62 9.95 6,273.59 11.81 -4.65 98.37 -5.69 11.55 4.56 7.92 135.55 23.48 145.64 MWD+IFR-AK-CAZ-SC(3,6) 14,000.00 91.62 9.95 6,270.77 11.91 -4.65 98.48 -5.69 11.65 4.56 7.95 135.62 23.56 145.67 MWD+IFR-AK-CAZ-SC(3,6) 14,037.55 91.62 9.95 6,269.71 11.94 -4.65 98.52 -5.69 11.68 4.56 7.96 135.64 23.59 145.68 MWD+IFR-AK-CAZ-SC(3,6) 14,100.00 90.06 10.00 6,268.80 11.75 -4.56 98.46 -5.70 11.75 4.56 7.98 135.66 23.55 145.69 MWD+IFR-AK-CAZ-SC(3,6) 14,102.26 90.00 10.00 6,268.80 11.75 -4.56 98.46 -5.70 11.75 4.56 7.98 135.66 23.55 145.69 MWD+IFR-AK-CAZ-SC(3,6) 14,200.00 90.00 12.44 6,268.80 11.85 -4.56 94.52 -5.83 11.85 4.56 8.02 135.69 23.43 145.69 MWD+IFR-AK-CAZ-SC(3,6) 14,266.87 90.00 14.12 6,268.80 11.92 -4.56 91.76 -5.92 11.92 4.56 8.04 135.71 23.40 145.70 MWD+IFR-AK-CAZ-SC(3,6) 14,300.00 90.00 14.12 6,268.80 11.96 -4.56 91.79 -5.92 11.96 4.56 8.05 135.73 23.41 145.71 MWD+IFR-AK-CAZ-SC(3,6) 14,400.00 90.00 14.12 6,268.80 12.07 -4.56 91.90 -5.92 12.07 4.56 8.08 135.79 23.52 145.74 MWD+IFR-AK-CAZ-SC(3,6) 14,499.98 90.00 14.12 6,268.80 12.17 -4.56 92.02 -5.92 12.17 4.56 8.11 135.85 23.62 145.78 MWD+IFR-AK-CAZ-SC(3,6) 14,500.00 90.00 14.12 6,268.80 12.17 -4.56 92.02 -5.92 12.17 4.56 8.11 135.85 23.62 145.78 MWD+IFR-AK-CAZ-SC(3,6) 14,600.00 90.00 17.62 6,268.80 12.29 -4.56 86.06 -6.10 12.29 4.56 8.14 135.90 23.66 145.81 MWD+IFR-AK-CAZ-SC(3,6) 14,696.69 90.00 21.00 6,268.80 12.39 -4.56 80.03 -6.26 12.39 4.56 8.17 135.94 23.64 145.83 MWD+IFR-AK-CAZ-SC(3,6) 14,700.00 89.88 21.00 6,268.80 12.40 -4.55 80.02 -6.26 12.40 4.56 8.17 135.94 23.63 145.83 MWD+IFR-AK-CAZ-SC(3,6) 14,800.00 86.38 21.03 6,272.06 14.40 -4.38 79.92 -6.27 12.51 4.56 8.20 135.95 23.40 145.82 MWD+IFR-AK-CAZ-SC(3,6) 14,900.00 82.88 21.05 6,281.41 18.80 -4.19 79.82 -6.27 12.63 4.57 8.24 135.96 23.17 145.81 MWD+IFR-AK-CAZ-SC(3,6) 14,902.64 82.79 21.05 6,281.74 18.93 -4.19 79.82 -6.27 12.63 4.57 8.24 135.96 23.17 145.81 MWD+IFR-AK-CAZ-SC(3,6) 15,000.00 82.79 21.05 6,293.95 19.01 -4.19 79.86 -6.27 12.74 4.59 8.28 135.99 23.12 145.83 MWD+IFR-AK-CAZ-SC(3,6) 15,006.96 82.79 21.05 6,294.83 19.01 -4.19 79.86 -6.27 12.75 4.59 8.29 135.99 23.12 145.83 MWD+IFR-AK-CAZ-SC(3,6) 15,041.51 84.00 21.00 6,298.80 17.37 -4.26 80.00 -6.26 12.79 4.59 8.30 136.01 23.16 145.84 MWD+IFR-AK-CAZ-SC(3,6) 15,100.00 85.91 20.25 6,303.94 15.14 -4.37 81.43 -6.23 12.86 4.60 8.33 136.04 23.23 145.87 MWD+IFR-AK-CAZ-SC(3,6) 15,200.00 89.17 18.99 6,308.24 13.09 -4.55 83.84 -6.15 12.98 4.60 8.36 136.09 23.33 145.90 MWD+IFR-AK-CAZ-SC(3,6) 15,286.92 92.01 17.89 6,307.34 13.58 -4.72 85.91 -6.09 13.08 4.60 8.39 136.14 23.43 145.93 MWD+IFR-AK-CAZ-SC(3,6) 15,300.00 92.01 17.89 6,306.88 13.60 -4.72 85.92 -6.09 13.10 4.60 8.40 136.15 23.45 145.94 MWD+IFR-AK-CAZ-SC(3,6) 15,400.00 92.01 17.89 6,303.38 13.72 -4.72 86.06 -6.09 13.22 4.60 8.43 136.21 23.60 145.98 MWD+IFR-AK-CAZ-SC(3,6) 15,500.00 92.01 17.89 6,299.87 13.83 -4.72 86.20 -6.09 13.35 4.59 8.46 136.27 23.76 146.03 MWD+IFR-AK-CAZ-SC(3,6) 15,600.00 92.01 17.89 6,296.37 13.95 -4.72 86.35 -6.09 13.47 4.59 8.49 136.33 23.93 146.07 MwD+IFR-AK-CAZ-SC(3,6) 15,700.00 92.01 17.89 6,292.87 14.08 -4.72 86.50 -6.09 13.60 4.59 8.52 136.40 24.11 146.12 MWD+IFR-AK-CAZ-SC(3,6) 15,800.00 92.01 17.89 6,289.36 14.20 -4.72 86.65 -6.09 13.72 4.59 8.56 136.46 24.29 146.16 MWD+IFR-AK-CAZ-SC(3,6) 15,900.00 92.01 17.89 6,285.86 14.32 -4.72 86.81 -6.09 13.85 4.58 8.59 136.53 24.47 146.21 MWD+IFR-AK-CAZ-SC(3,6) 16,000.00 92.01 17.89 6,282.35 14.45 -4.72 86.96 -6.09 13.98 4.58 8.62 136.60 24.67 146.26 MWD+IFR-AK-CAZ-SC(3,6) 16,100.00 92.01 17.89 6,278.85 14.58 -4.72 87.13 -6.09 14.11 4.58 8.66 136.67 24.87 146.31 MWD+IFR-AK-CAZ-SC(3,6) 16,200.00 92.01 17.89 6,275.34 14.70 -4.72 87.29 -6.09 14.24 4.58 8.69 136.74 25.07 146.36 MWD+IFR-AK-CAZ-SC(3,6) 16,300.00 92.01 17.89 6,271.84 14.83 -4.72 87.47 -6.09 14.38 4.57 8.73 136.81 25.29 146.41 MWD+IFR-AK-CAZ-SC(3,6) 16,400.00 92.01 17.89 6,268.33 14.96 -4.72 87.64 -6.09 14.51 4.57 8.76 136.88 25.50 146.46 MWD+IFR-AK-CAZ-SC(3,6) 16,500.00 92.01 17.89 6,264.83 15.09 -4.72 87.82 -6.09 14.65 4.57 8.80 136.95 25.73 146.51 MWD+IFR-AK-CAZ-SC(3,6) 16,600.00 92.01 17.89 6,261.32 15.22 -4.72 88.00 -6.09 14.78 4.56 8.84 137.02 25.95 146.57 MWD+IFR-AK-CAZ-SC(3,6) 16,700.00 92.01 17.89 6,257.82 15.36 -4.72 88.18 -6.09 14.92 4.56 8.87 137.10 26.19 146.62 MWD+IFR-AK-CAZ-SC(3,6) 16,800.00 92.01 17.89 6,254.31 15.49 -4.72 88.37 -6.09 15.05 4.56 8.91 137.17 26.43 146.68 MWD+IFR-AK-CAZ-SC(3,6) 16,900.00 92.01 17.89 6,250.81 15.62 -4.72 88.56 -6.09 15.19 4.56 8.95 137.25 26.67 146.74 MwD+IFR-AK-CAZ-SC(3,6) 16,957.32 92.01 17.89 6,248.80 15.70 -4.72 88.67 -6.09 15.27 4.56 8.97 137.29 26.81 146.77 M960+IFR-AK-CAZ-SC(3,6) 8/24/2016 11:40:19AM Page 4 COMPASS 5000.1 Build 74 • i Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Site: Kuparuk 2S Pad MD Reference: Plan:119.8+39(Doyon 142)@ 158.80usft Well: 2S-13 North Reference: True Wellbore: Plan:2S-13A Survey Calculation Method: Minimum Curvature Design: 2S-13Awp19 Output errors are at 1.00 sigma Database: OAKEDMP2 Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2S-13A Tgt 4 A3 08181E 0.00 0.00 6,248.80 6,469.72 -4,479.59 5,936,179.00 1,616,469.00 70°14'13.687 N 150°11'36.117 W -plan hits target center -Circle(radius 100.00) 2S-13ATgt 2 A3 08181E 0.00 0.00 6,268.80 4,329.64 -5,197.14 5,934,041.00 1,615,746.00 70°13'52.634 N 150°11'56.929 W -plan hits target center -Circle(radius 100.00) 2S-13ATgt 1 A3 08181E 0.00 0.00 6,268.80 3,755.20 -5,347.67 5,933,467.00 1,615,594.00 70°13'46.983 N 150°12'1.292 W -plan hits target center -Circle(radius 100.00) 2S-13A Tgt 3 A3 08181E 0.00 0.00 6,298.80 4,649.99 -5,073.95 5,934,361.00 1,615,870.00 70°13'55.785 N 150°11'53.356 W -plan hits target center -Circle(radius 100.00) 2S-13A Tgt 0 7-5/8 0818 0.00 0.00 6,331.80 22.31 -5,928.09 5,929,736.00 1,615,004.00 70°13'10.264 N 150°12'18.070 W -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter ,° (usft) (usft) Name (1 (") 2,846.50 2,559.28 13-3/8"x 16" 13-3/8 16 10,315.83 6,331.80 7-5/8"x 9-5/8" 7-5/8 9-7/8 16,957.32 6,248.80 41/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 9,218.63 5,974.80 THRZ 0.00 9,469.17 6,089.80 U Kalubik 0.00 9,674.73 6,171.80 Kalubik(K-1) 0.00 9,959.86 6,261.80 Kup C(Top C4) 0.00 10,002.77 6,272.80 A4 0.00 10,251.59 6,322.80 A3 0.00 Checked By: Approved By: Date: 8/24/2016 11:40.19AM Page 5 COMPASS 5000.1 Build 74 Pool Report • • r ggsos 00 ci <ici f4sf48 T CO N 11115 =w Z i a i O ° . 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B N:' 4 E i a 2 N • 0 '2 § C < ,,, z . 1 O V6 -0 0 *.r....! 1 E i i 1 U i 3 -J = cn E, , ,5,_ o L c„.. (..... t., 2 L. g. S - s . '? .3 L co 1 n 5 0 co w ° ' c! 1 -; ig 4 N t a, .__1 0 ',' -8 E § 1 L., 2 N N o ,,, o 0 . z 3. m c ..< __I $ r, 2 - O O .2 m JP 7 3 ‘) § _7:9 171 E F E ro 2C) , . i f u 6: ,7,' a 0 As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY ,. APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 per K150013ACS NOTES: •.n CO rr to is ♦14 iA i:s .a +z ,; . CD w � y,► 41 1. BASIS OF LOCATION AND ELEVATION IS DS2S w3'9 21 22 23 14 20 MONUMENTATION PER LOUNSBURY & ASSOC. 1 7,CPP2 I 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES _ •�� ARE NAD 27. ! --'$ ° r•,,,, Dm _ 3 T11N 3. ELEVATIONS ARE B.P.M.S.L. ___....../.---7-1_,,,,-�oP •° 3 1 �� s 3 T1ON 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTEDee .v SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, .43 I 9 IS I ,. ' UMIAT MERIDIAN. .---'�r`� t8 tb 35 14 /3 18 ' 11111111. 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS Q L15-28, L15-29, L15-32, L15-35, 11-13-2015 z., - FIELD BOOK L15-75. '3 2, PROJECT 24 B LOCATION 6. ALL DISTANCES SHOWN ARE TRUE. 25 40 2 2 I 27 V,. ss 37 29 38 27 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR I 13. 3 a2 '- n 3" 33 31 , 32 31 34 N VICINITY MAP NTS I —427_ / ,., 30, -T'6°.DS2S --1 1 6 4 • . 141210. 8 . 5321 13 15 11 9 LEGEND ® AS—BUILT CONDUCTOR LOCATION \ 17+16 • EXISTING CONDUCTOR LOCATIONS 20 21 GRAPHIC SCALE 0 100 200 400 1 ..* LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS 41 IPPV AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 1 OF 2 I 2 i REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add WeII 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70° 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70° 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150° 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70° 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150° 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70° 13' 11.496" 150° 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' * 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. +'�P� 41® ® SURVEYOR'S CERTIFICATE i •' 49 '\ ♦® I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND $ ' ', LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 0 _ Al ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND <^�' JEREMIAH F. CORNELL, ff1 ♦ . , r THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ® t'P •• LS-12663 o ;,.a FOA0. AS OF NOVEMBER 13, 2015. il®r a:;®I: LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 2 I • Attachment 3 - 2S-13A Drilling Hazards Summary 9-7/8" Intermediate#2 Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Moderate Lost circulation has occurred on offset wells 2S-07&2S- 02 in the immediate hole. Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tarn formations crossed in intermediate. Apply wellbore strengthening mud additives. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Production Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • Attachment 4 — 2S-13A Cement Summary 7-5/8"Intermediate#2 Liner run to TD(i 10,316'MD/6,332'TVD bring cement to liner top na,8958' MD/5846' TVD Cement from 10,316'MD to 8,958'with 15.8 ppg Class G(-180' inside 10-3/4"liner). Assume 40%excess annular volume. Tail slurry: (10,316'—9,138')X 0.2145 ft3/ft X 1.4(40%excess)=354 ft3 annular volume (9,138-8,958')X 0.2145 ft3/ft X 1.0(0%excess)=39 ft3 annular volume 80'X 0.2483 ft3/ft=20 ft3 shoe joint volume Total volume=354 ft3+39 ft3+20 ft3=>353 Sx @ 1.17 ft3/sk System: 353 Sx 15.8 ppg Class G • • Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, September 14,2016 2:10 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2S-13A(PTD 216-104) BOP test pressure Follow Up Flag: Follow up Flag Status: Flagged Ah, OK. Apologies, must have missed it when writing it down. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,September 14,2016 2:08 PM To: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2S-13A(PTD 216-104) BOP test pressure Yes,that's what I need. The BOP test pressure is usually specified in the PTD although it generally is 3500 psig. From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, September 14, 2016 1:49 PM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2S-13A(PTD 216-104) BOP test pressure Not sure what you might be asking, but I assume the answer is standard 3500 psi on rams&2500 psi on the annular (250 psi low). From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,September 14,2016 1:43 PM To: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]KRU 2S-13A(PTD 216-104)BOP test pressure Scott, What is the BOP test pressure for this well? 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 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 1 • Bettis, Patricia K (DOA) /3--J./ —16(1 From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, August 31, 2016 3:12 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-13 and KRU 2S-13L1 Yes, however, I have been told it will be a much shorter period. Perhaps a month to let the well clean up. From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, August 31, 2016 2:50 PM To: Brunswick, Scott A<Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]FW: KRU 2S-13 and KRU 2S-13L1 Scott, Does the original plan for pre-production still hold true for replacement wells KRU 2S-13A and KRU 2S-13AL1? Thank you, Patricia From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent:Thursday, August 27, 2015 7:15 AM To: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: RE: KRU 2S-13 and KRU 2S-13L1 Patricia I've been told that the primary purpose of the pre-production is to draw down the pressure to assist in drilling the future wells in the program safer. I've also been told that if the pressure remains high they intend to keep production on for the 6 month period, but if pressure declines too quickly they will discontinue pressure to avoid formation damage/reaching bubble point). I can ask the production team to further explain if this isn't sufficient. Thanks Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.00v] Sent: Wednesday, August 26, 2015 1:33 PM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2S-13 and KRU 2S-13L1 Scott, ConocoPhillips should provide justification on why these injections wells will be pre-produced for more than 3 months. Thank you, Patricia 1 • • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME:� a3- 13 j- PTD: off« —101 Development " Service Exploratory Stratigraphic Test Non-Conventional FIELD: POOL: XaJ. ?t l/&r' gyirkitAR /r)VG! Or/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • E TuN a)• a , co N O @ 4) a • Q0 a ; ; , ; ; L d C O 0, C Z m m a0' co �' E O• 3 �, rn u) Es. ' ° ° o `0) c '�� �; �, o o a ' 3; %; 3' coQ ° �, ' m; @ d of a a in o co c O. .0 a> E , -a , .o. a E. o ° D C' = ca: 0? d p ! M' C: �: Ca N -� a' 0 O, ' <� E , p_ , O Qj , O. 0 p . N. , O n' N a)' , .L..» _� -) X; N, Y; a; '� 3; 0, N• ; —; N. N; o; co O. a o af, Y; °c; ° o �; c �; 3; @ o y; c'n, 3 '3 n; '9; 0, , =y, t a co. �, E a N' @ Y. a) 5 a x' c >, ,a2N .y ami Y CCi .0 3. Y aoi co , > 5 c �, �, o w rn y; :° m ° a N 4Y v) �, < ri Q a, O. @ CO CO N •c, •c. C: ate' ,Nn c p; p, �_ Qy N. CO 0. 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I- a QLu- E a w Q > Q a U a Q • • Well History Ale APPENDIX InfoilHHation 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.
