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176-074
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,630 feet 9,950 feet true vertical 9,103 feet 10,502 feet Effective Depth measured 9,950 feet 2,415 & 10,009 feet true vertical 8,525 feet 2,317 & 8,575 feet Perforation depth Measured depth 2,640 - 5,688 feet True Vertical depth 2,521 - 4,999 feet 3-1/2" 9.2 / L-80 2,446 MD 2,345 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / L-80 10,012 MD 8,577 TVD HS Ret PKR 2,415 (MD) 2,317 (TVD) Packers and SSSV (type, measured and true vertical depth)HES Perm Pkr 10,009 (MD) 8,575 (TVD) T-5 SSSV 307 (MD) 307 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse 520psi Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 1,530psi 3,090psi 907 777-8376 5,750psi 718 2,387 9,103 718 2,492 Conductor Surface 3,090psi 20" 13-3/8" 10,630 Size 128 Production Casing Structural Liner Length Intermediate N/A Junk 5. Permit to Drill Number: 0 McArthur River Field / Middle Kenai G Oil & Middle Kenai Gas PoolsN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 130 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-418 626 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 176-074 50-733-20215-01-00 Plugs ADL0018729 Trading Bay Unit D-31RD measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 6440 Casing Pressure 10,630 MD 718 2,492 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:03 am, Nov 10, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.09 16:01:04 -09'00' Dan Marlowe (1267) SFD 11/10/2020DSR-11/10/2020 RBDMS HEW 11/10/2020 Perforate gls 11/23/20 _____________________________________________________________________________________ Updated By: JLL 11/06/20 SCHEMATIC McArthur River Field, TBU Well: D-31RD Completed: 10/11/2014 RKB = 40.5’ TD = 10,630’’ PBTD = 10,593’ 3 1 4 12 13-3/8” 9-5/8” 20” 13 2 Casing Damage 2,480’-3,420’5 6 7 8 11 GGS SZ10 GGS SZ11 D-2 G-2 G-3 G-4 G-4 D-4 TOC ~4,800’ 10 Max Angle=38.6° @ 4,917’ 14 9 Stage Collar @ 7,077’ X X CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 94 H-40 19.124 Surface 718’ 13-3/8” 61 K-55 Seal Lock 12.51 Surface 2,492’ 9-5/8” 40 N-80 BTC 8.835 Surface 2,783’ 9-5/8” 47 N-80 BTC 8.681 2,783’ 8,366’ 9-5/8” 47 P-110 BTC 8.681 8,366’ 10,630’ Tubing 3-1/2” 9.2# L-80 Supermax 2.992 Surf 2,446’ 3-1/2” 9.2# L-80 Butt SC 2.992 9,601’ 10,012’ JEWELRY DETAIL NO. Depth (MD) Depth (TVD) ID OD Item 40.50’40.50’- - Tubing Hanger w/pup 1 307’ 307’2.992 3.500 T-5 SSSV 2 2,363’ 2,270’2.992 3.500 GLM 3 2,415’ 2,317’2.992 9.625 HS Retrievable Packer 4 2,437’ 2,337’2.813 4.880 X-Nipple 5 2,447’ 2,346’2.970 4.480 WLEG 6 9,601’ 8,233’2.992 3.500 Top of tubing E-Line cut 7 9,930’ 8,509’3.00 5.968 McMurry Macco, 3-1/2” SMO-2 GLM , 1-1/2”, RK w/ OGLV installed 11/25/08. 8 9,950’ 8,525’--CIBP 9 10,012’ 8,577’3.06 4.500 HES, No-Go Seal Assembly, 10’, Molded 10 10,009’ 8,575’4.00 8.120 HES, 9-5/8”, 36#-59.4#, ‘BWD’ Permanent Packer 11 10,013’ 8,578’4.00 5.020 HES, Seal Bore Extension, 8’ Long 12 10,021’ 8,585’ 2.992 5.720 HES, Tubing Adapter 13 10,032’ 8,594’ 2.813 3.970 HES, ‘X’ Nipple, 2.813 14 10,041 8,602’ 2.992” 6.030 WLEG Fish: 10/22/1993 2.74” O.D. Overshot & Rope Socket,15”Long Disconnect, XO, 2-3/8” Drillex Motor, 2.625” Wash Pipe and Shoe 09/28/1986 32’ of 2-5/8” Perf Gun top at 10,502’ Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Condition Date GGS SZ10 2,640' 2,658' 2,521' 2537' 18' Open 10/07/15 GGS SZ11 2,760' 2,770' 2,627' 2,636' 10' Open 10/07/15 D2 5,348’ 5,368’ 4,742’ 4,758’ 20’ Open 10/31/20 D4 Lower 5,651’ 5,668’ 4,985 4,999’ 17’ Open 10/30/20 G-2 10,240' 10,275' 8,770' 8,799' 35' Isolated 3/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Isolated 3/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 3/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/1/1990 D-4 D-2 D2 5,348’ 5,368’ 4,742’ 4,758’ 20’ Open 10/31/20 D4 Lower 5,651’ 5,668’ 4,985 4,999’ 17’ Open 10/30/20 Well Name Rig API Number Well Permit Number Start Date End Date D-31RD Eline 50-733-20215-01-00 176-074 10/30/2020 10/31/2020 Daily Operations: 10/30/2020 - Friday Arrive on the Dolly, Get orientation, PJSM & Permits. Offload Eline equipment to deck. MIRU, make up riser to WH to drill deck, pu top sheave, make up GR/CCL, test wire. Good test. Make up Gun #1, 17', 2.375", 5 spf, 60* phasing, 11gram, razor gun.,Stab on well, Fluid pack for pt. PT Lub/WLV low/high 250/1500. Test good. Open well, Swab 20 turns, T/IA/= 80/130. RIH, @5800' pull correlation log up to 4990', send t/ town for approval to shoot D4 Lower 5651'-5668'. Make 3.5' correction, re-log from 5800'-5470', send log t/town for evaluation. Make -2' correction. Log is now on depth. Approval to shoot D4 lower sands (Geologist)5651'-5668'. RIH to 5800' pu to CCL depth 5640.4. CCL t/top shot 10.6', CCL t/bottom shot 27.6. Shoot D4 lower sands 5651'-5668' ITP 46, FTP 46. Log up 200'. POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired. Wet Bullnose. Turn well over to production. 10/31/2020 - Saturday PJSM & Permits. Standby for plan forward. Got the go ahead to rig up for second set of perfs in the D2 sands. 5348'-5368'. Rig up Gun #2. 20', 2.375", 5spf, 60* phasing, 11gram, razor gun. Stab on well, Open up, Swab 24, WHP 100, IA 130. RIH, Find fluid level around 457'. Continue in hole to pull logging pass. @ 5600' log up to 5100', send log to town for approval to shoot D2 sands 5348'-5368'. Got approval to shot D2 5348'-5368' (Geologist). RIH to 5600', pu getting on CCL depth 5339.8'. CCL t/top shot 8.2' CCL t/bottom shot 28.2'. Shoot D2 sand 5348'-5368'. Gun did not fire. POOH check tools. Tagged up, swab shut, bleed down, pop off well. Check tear drop on gun. Didn't have connection. Bad ground on firing head. Put new teardrop on. Test connection. Good test. Stab on well. Open well, RIH, @5600', Pu tying into log getting on depth. RIH to 5600', PU getting on CCL depth 5339.8'. CCL t/top shot 8.2' CCL t/bottom shot 28.2'. Shoot D2 sand 5348'-5368'. ITP 90, FTP 90. No change. Log up 200'. POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired. Wet gun. RDMO. Standby for Helicopter. Leave Dolly Varden. Arrive at OSK. Hilcorp Alaska, LLC Well Operations Summary 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: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai G Oil & Middle Kenai Gas Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,630'10,502' Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate Production 3,090 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 9,950' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 176-074 50-733-20215-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit D-31RD CO 228A 9.2# / L-80 TVD Burst 2,446 & 10,012 5,750 psi Tubing Size: MD 1,530 psi 3,090 psi 718' 2,387' 718' 2,492' 20" 13-3/8" 718' 2,492' 10,630' Perforation Depth MD (ft): 2,640 - 2,770 10,630' 2,415 (MD) 2,317 (TVD) / 10,009 (MD) 8,575 (TVD) & 307 (MD) 307 (TVD) Tubing Grade:Tubing MD (ft): 2,521 - 2,636 Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 10/17/2020 3-1/2" Daniel E. Marlowe HS Ret Pkr & HES Perm Pkr / T-5 SSSV 9,103'9,950'8,525'~1260psi 9,103'9-5/8" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:16 am, Oct 05, 2020 320-418 Daniel Marlowe I am approving this document 2020.10.05 05:21:55 -08'00' Daniel Marlowe gls 10/12/20 DSR-10/12/2020 X Perforate 10-404 DLB 10/05/2020 Comm. tion Required? Yes 10/13/2020 dts 10/13/2020 JLC 10/13/2020 RBDMS HEW 11/3/2020 Well Work Prognosis Well Name:Trading Bay Unit D-31RD API Number: 50-733-20215-01 Current Status:Gas Well Leg:A-1 (NE corner) Estimated Start Date:10/17/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:176-074 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8384 Cell: 907-570-1801 Current Bottom Hole Pressure: 1,158 psi @ 2,579’ TVD 0.449 psi/ft Maximum Expected BHP:1,398 psi @ 5900’ TVD 0.449 psi/ft Maximum Potential Surface Pressure: (Perf Job):~1,260 psi using 0.1 psi/ft Brief Well Summary: Well D-31RD is a gas well currently completed in the SZ and G sands. The objective is to perforate the D-2 and D-4 sands. Note: Cement data will be updated on the schematic and sent separately. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate per the program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Well D-31RD is a gas well currently completed in the SZ and G sands. The objective is to perforate the D-2 and D-4 sands. _____________________________________________________________________________________ Updated By: JLL 10/08/15 SCHEMATIC McArthur River Field, TBU Well: D-31RD Completed: 10/11/2014 RKB = 40.5’ TD = 10,630’’ PBTD = 10,593’ 3 1 4 12 13-3/8” 9-5/8” 20” 13 2 Casing Damage 2,480’-3,420’ 5 6 7 8 11 10 Max Angle=38.6° @ 4,917’ 14 9 Stage Collar @ 7,077’ X X CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 94 H-40 19.124 Surface 718’ 13-3/8” 61 K-55 Seal Lock 12.51 Surface 2,492’ 9-5/8” 40 N-80 BTC 8.835 Surface 2,783’ 9-5/8” 47 N-80 BTC 8.681 2,783’ 8,366’ 9-5/8” 47 P-110 BTC 8.681 8,366’ 10,630’ Tubing 3-1/2” 9.2# L-80 Supermax 2.992 Surf 2,446’ 3-1/2” 9.2# L-80 Butt SC 2.992 9,601’ 10,012’ JEWELRY DETAIL NO. Depth ID OD Item 40.50’ - - Tubing Hanger w/pup 1 307’ 2.992 3.500 T-5 SSSV 2 2,363’ 2.992 3.500 GLM 3 2,415’ 2.992 9.625 HS Retrievable Packer 4 2,437’ 2.813 4.880 X-Nipple 5 2,447’ 2.970 4.480 WLEG 6 9,601’ 2.992 3.500 Top of tubing E-Line cut 7 9,930’ 3.00 5.968 McMurry Macco, 3-1/2” SMO-2 GLM , 1-1/2”, RK w/ OGLV installed 11/25/08. 8 9,950’ - - CIBP 9 10,012’ 3.06 4.500 HES, No-Go Seal Assembly, 10’, Molded 10 10,009’ 4.00 8.120 HES, 9-5/8”, 36#-59.4#, ‘BWD’ Permanent Packer 11 10,013’ 4.00 5.020 HES, Seal Bore Extension, 8’ Long 12 10,021’ 2.992 5.720 HES, Tubing Adapter 13 10,032’ 2.813 3.970 HES, ‘X’ Nipple, 2.813 14 10,041 2.992” 6.030 WLEG Fish: 10/22/1993 2.74” O.D. Overshot & Rope Socket,15”Long Disconnect, XO, 2-3/8” Drillex Motor, 2.625” Wash Pipe and Shoe 09/28/1986 32’ of 2-5/8” Perf Gun top at 10,502’ Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Condition Date GGS SZ10 2,640' 2,658' 2,521' 2537' 18' Open 10/07/15 GGS SZ11 2,760' 2,770' 2,627' 2,636' 10' Open 10/07/15 G-2 10,240' 10,275' 8,770' 8,799' 35' Isolated 3/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Isolated 3/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 3/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/1/1990 _____________________________________________________________________________________ Updated By: JLL 09-29-20 PROPOSED McArthur River Field, TBU Well: D-31RD Completed: 10/11/2014 RKB = 40.5’ TD = 10,630’’ PBTD = 10,593’ 3 1 4 12 13-3/8” 9-5/8” 20” 13 2 Casing Damage 2,480’-3,420’5 6 7 8 11 GGS SZ10 GGS SZ11 D-2 G-2 G-3 G-4 G-4 D-4 10 Max Angle =38.6° @4,917’ 14 9 Stage Collar @ 7,077’ X X CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 94 H-40 19.124 Surface 718’ 13-3/8” 61 K-55 Seal Lock 12.51 Surface 2,492’ 9-5/8” 40 N-80 BTC 8.835 Surface 2,783’ 9-5/8” 47 N-80 BTC 8.681 2,783’ 8,366’ 9-5/8” 47 P-110 BTC 8.681 8,366’ 10,630’ Tubing 3-1/2” 9.2# L-80 Supermax 2.992 Surf 2,446’ 3-1/2” 9.2# L-80 Butt SC 2.992 9,601’ 10,012’ JEWELRY DETAIL NO. Depth (MD) Depth (TVD) ID OD Item 40.50’40.50’- - Tubing Hanger w/pup 1 307’ 307’2.992 3.500 T-5 SSSV 2 2,363’ 2,270’2.992 3.500 GLM 3 2,415’ 2,317’2.992 9.625 HS Retrievable Packer 4 2,437’ 2,337’2.813 4.880 X-Nipple 5 2,447’ 2,346’2.970 4.480 WLEG 6 9,601’ 8,233’2.992 3.500 Top of tubing E-Line cut 7 9,930’ 8,509’3.00 5.968 McMurry Macco, 3-1/2” SMO-2 GLM , 1-1/2”, RK w/ OGLV installed 11/25/08. 8 9,950’ 8,525’--CIBP 9 10,012’ 8,577’3.06 4.500 HES, No-Go Seal Assembly, 10’, Molded 10 10,009’ 8,575’4.00 8.120 HES, 9-5/8”, 36#-59.4#, ‘BWD’ Permanent Packer 11 10,013’ 8,578’4.00 5.020 HES, Seal Bore Extension, 8’ Long 12 10,021’ 8,585’ 2.992 5.720 HES, Tubing Adapter 13 10,032’ 8,594’ 2.813 3.970 HES, ‘X’ Nipple, 2.813 14 10,041 8,602’ 2.992” 6.030 WLEG Fish: 10/22/1993 2.74” O.D. Overshot & Rope Socket,15”Long Disconnect, XO, 2-3/8” Drillex Motor, 2.625” Wash Pipe and Shoe 09/28/1986 32’ of 2-5/8” Perf Gun top at 10,502’ Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Condition Date GGS SZ10 2,640' 2,658' 2,521' 2537' 18' Open 10/07/15 GGS SZ11 2,760' 2,770' 2,627' 2,636' 10' Open 10/07/15 D2 ±5,348’ ±5,369’ ±4,742 ±4,759 ±21’ Proposed Future D4 Lower ±5,651’ ±5,668’ ±4,985 ±,4999 ±17’ Proposed Future G-2 10,240' 10,275' 8,770' 8,799' 35' Isolated 3/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Isolated 3/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 3/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/1/1990 D2 ±5,348’±5,369’±4,742 ±4,759 ±21’Proposed Future D4 Lower ±5,651’±5,668’±4,985 ±,4999 ±17’Proposed Future STATE OF ALASKA AL OIL AND GAS CONSERVATION COMADION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ID Repair Well ❑ Re-enter Susp Well❑ Other: Convert to Gas Producer 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development C Exploratory❑ 176-074 A 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20215-01 7.Property Designation(Lease Number): 8.Well Name and Number: C F V F ADL0018729 • Trading Bay Unit D-31RD v 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Gas ')fl C T 20 ",,n1' N/A McArthur River Field/Middle KenaL., WPool • 11.Present Well Condition Summary: AOti -: Total Depth measured 10,630 I feet Plugs measured 9,950 feet true vertical 9,103 ' feet Junk measured 10,502 feet Effective Depth measured 9,950 feet Packer measured 2,415&10,009 feet true vertical 8,525 feet true vertical 2,317&8,575 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 718' 20" 718' 718' 1,530 psi 520 psi Surface 2,492' 13-3/8" 2,492' 2,387' 3,090 psi 1,540 psi Intermediate Production 10,630' 9-5/8" 10,630' 9,103' 5,750 psi 3,090 psi Liner Perforation depth Measured depth 2,640-10,426 feet SCANNED Nov 03 is True Vertical depth 2,521 -8,928 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 2,446&10,012 2,345&8,577 HS Retrievable Pkr 2,415'(MD)2,317'(TVD) Packers and SSSV(type,measured and true vertical depth) HES Perm.Pkr 10,009'(MD)8,575'(TVD) T-5 SSSV 307'(MD)307'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1000 980 Subsequent to operation: 0 992 0 360 790 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development ' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 315-542 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signaturer Phone (907)283-1329 Date 10/19/2015 -14 6' :3.1 S f RBDMS Nit 1 CT 2 12015 Form 10-404 Revised 5/2015 ,- Submit Original Only A (D7 71 McArthur River Field, TBU • . ti SCHEMATIC • Well: D-31RD ,.. Completed: 10/11/2014 Hikurp Alaska,LLC RKB-40.5' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 H-40 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' 20" 1 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing _ 3-1/2" 9.28 L-80 Supermax 2.992 Surf 2,446' 3-1/2" 9.2# L-80 Butt SC 2.992 9,601' 10,012' JEWELRY DETAIL NO. Depth ID OD Item 13-3/8" 2 40.50' - - Tubing Hanger w/pup 1 307' 2.992 3.500 T-5 SSSV 3 2 2,363' 2.992 3.500 GLM 3 2,415' 2.992 9.625 HS Retrievable Packer Casing 117-11( 1 4 4 2,437' 2,813 4.880 X-Nipple Damage C� 5 5 2,447' 2.970 4.480 WLEG 2,480-3,420' 6 9,601' 2.992 3.500 Top of tubing E-Line cut 7 9,930' 3.00 5.968 McMurry Macco,3-1/2"SMO-2 GLM,1-1/2",RK wl OGLV installed 11/25/08. 8 9,950' - - CIBP stage _I - 9 10,012' 3.06 4.500 HES, No-Go Seal Assembly,10',Molded collar @ 7,077 - - 10 10,009' 4.00 8.120 HES,9-5/8",36#-59.4#,'BWD'Permanent Packer 11 10,013' 4.00 5.020 HES,Seal Bore Extension, 8'Long 6 12 10,021' 2.992 5.720 HES,Tubing Adapter 13 10,032' 2.813 3.970 HES,'X'Nipple,2.813 7 14 10,041 2.992" 6.030 WLEG Jae 4, 8 > --. 1 9 10 Fish: ■ 10/22/1993 2.74"O.D.Overshot&Rope Socket,15"Long Disconnect,XO,2-3/8" ■ 11 Drillex Motor,2.625"Wash Pipe and Shoe J 12 09/28/1986 32'of 2-5/8"Perf Gun top at 10,502' on 13 Ei 14 Perforation History Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt Condition Date GGS SZ10 2,640' 2,658' 2,521' 2537' 18' Open 10/07/15 GGS SZ11 2,760' 2,770' _ 2,627' 2,636' 10' Open 10/07/15 G-2 10,240' 10,275' _ 8,770' 8,799' 35' Isolated 3/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Isolated 3/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 3/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/1/1990 9-5/8"/ I . TD=10,630" PBTD=10,593' Max Angle=38.6°@ 4,917' Updated By:JLL 10/08/15 • Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 10/7/15 10/7/15 Daily Operations: 10/07/15 -Wednesday Arrive at heliport and fly out to platform. Orientation,JSA, Permitting. Spot and rig up equipment. Rigged up to wellhead and pressure test lubricator to 1500 psi high/250 psi low. RIH w/ 10' of 2.5" spiral strip gun 4 spf, correlate on depth and perforate 2,760-2,770' (GGS SZ-11 sand). RIH w/ 18' of 2.5" spiral strip gun 4 spf, correlate on depth and perforate 2,640- 2,658' (GGS SZ-10 sand). POOH and rig down e-line equipment. • • Roby, David S (DOA) From: Dan Marlowe <dmarlowe@hiicorp.com> Sent: Thursday,October 22, 2015 9:17 AM To: Roby. David S (DOA) Cc: Juanita Lovett Subject: RE:Sundry ReporrferrTHCTD`31RE PTEI176= 4) You are correct sir This well was producing from the Middle Kenai G Oil Pool but will now be producing from the Middle Kenai Gas Pool From: Roby, David S (DOA) [mailto:dave.roby0alaska.aovj Sent: October 21, 2015 4:02 PM To: Dan Marlowe Subject: Sundry Report for TBU D-31RD (PTD 176-074 Dan, I'm review the above reference sundry report and it is for convert the well to a gas producer but on the report it lists the poo, as the Middle Kenai Oil Pool. We don't have an officially defined Middle Kenai Oil Pool but we do have a Middle Kenai G Oil Pool. However,the G oil sands are much deeper than the perforations you just added in the GGS sands. I believe the pool definition should actually be Middle Kenai Gas Pool,which is defined in CO 228A as the interval from 1,780 to 10,128 feet and in the TBU K-2 well but wanted to double check with you to make sure this is correct before we change it in our database. Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation L.ommission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged 'nformation.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 Dave Roby at (907)793-1232 or dave.roby@alaska.bov. 1 `•oF ry ,w�,,\��j�,s� THE STATE Alaska Oil and Gas �w �����'� of Conservation Commission F ALASKA •ti t#__ 333 West Seventh Avenue "Ill ti. GOVERNOR BILL WALKER Anchorage, AlasMaink9095071-3572 OF+�In, 4LA5ill'P Fax. 907 276 7542 www.aogcc.alaska.gov Dan Marlowe r-1 6 ... Q 7 Lt Operations Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: McArthur River Field, Middle Kenai Oil Pool, TBU D31 RD Sundry Number: 315-542 Dear Mr. Marlowe: 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, Zt,7 - ii—ea.,Ali, Cathy P. Foerster Chair DATED this 3 tday of September, 2015 Encl. RBDMkSEP 0 4 2015 RECEIVED QEF 0 1 2015. STATE OF ALASKA b-7-5 1121 \S ALASKA OIL AND GAS CONSERVATION COMMISSION AGOC APPLICATION FOR SUNDRY APPROVALS AO GOC AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 0 . Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redd!❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to Gas Producer J CI 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory El Development D • 176-074 3.Address 3800 Centerpoint Drive,Suite 1400Stratigraphic CI Service I] 6.API Number: Anchorage,AK 99503 50-733-20215-01 . 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes ❑ No 2 1 Trading Bay Unit/D-31 RD• 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL0018729 - McArthur River Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured) Junk(measured): . 10,630 - 9,103 . 10,593 • 9,071 9,950 10,502 Casing Length Size MD TVD Burst Collapse Structural Conductor 718' 20" 718' 718' 1,530 psi 520 psi Surface 2,492' • 13-3/8" 2,492' 2,387' 3,090 psi 1,540 psi Intermediate Production 10,630' • 9-5/8" 10,630' 9,103' 5,750 psi 3,090 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,240-10,426 , 8,770-8,928 3-1/2" 9.2#/L-80 2,446&10,012 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): HS Retrievable Pkr/HES Perm.Pkr&T-5 SSSV . 2,415'(MD)2,317'(TVD)/10,0c09'(MD)8,575'(TVD)&307'(MD)307'(TVD). 12.Attachments: Description Summary of Proposal 1=1 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ :velopment[L Service Cl 14 Estimated Date for 15.Well Status after proposed work 9/15/2015 Commencing Operations. OIL ❑ WINJ ❑ WDSP❑ Suspended El 16.Verbal Approval Date: GAS 0 , WAG ❑ GSTOD SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer /v b7e-i , LGY 1:94--0-e-- Signature c— - Signature '� �--"7�t����`� Phone (907)283-1329 Date 9/1/2015 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number: 1 Plug Integrity CI BOP Test CI Mechanical Integrity Test CI Location Clearance CIL, Other. Spacing Exception Required? Yes ❑ No Z Subsequent Form Required 1()"10 11 APPROVED BY ? S Approved by. P g COMMISSIONER THE COMMISSION Date: J 40, qi.ilis 7/2-7 4 J RBDMS §t--130 3 2015 m�§t--13orman �JNAL Form 10 403 Revised 5/2015 A p e ptfor 12 months from the date of approval. Attach is in Duplicate Well Prognosis • Well: D-31rd Hi'carp Alaska,LLC Date: 08/31/15 Well Name: D-31rd API Number: 50-733-20215-01 Current Status: SI producer Leg: Leg#A-1 NE corner Estimated Start Date: September 15, 2015 Rig: N/A (E-Line) Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 176-074 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420'(0) (985) 867-0665 (M) Current Bottom Hole Pressure: 1,100 psi @ 2,636'TVD 0.417 psi/ft shut-in surface pressure with gas column Maximum Expected BHP: 1,100 psi @ 2,636'TVD 0.417 psi/ft shut-in surface pressure with gas column Max.Allowable Surface Pressure(Pert Job): -1,200 psi gas-lift pressure Brief Well Summary Well D-31rd is a shut-in oil G-Zone producer. In 2014 Hilcorp attempted to workover this well but could not finish the re-complete due to casing damage in the GGS pressuring up the well.This perf work will allow us to bleed down these GGS SZ sands. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate SZ-10& 11 sands. Record tubing pressures before and after perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic McArthur River Field, TBU SCHEMATIC Well: D-31RD Completed: 10/11/2014 Hilruq Alaska,LLC CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 H-40 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' RKB=40.5' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' - 9-5/8" 47 N-80 _ BTC 8.681 2,783' 8,366' 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing 3-1/2" 9.2# L 80 Supermax 2.992 Surf 2,446' 20" l 1- 1 3-1/2" 9.2# L-80 Butt SC 2.992 9,601' 10,012' JEWELRY DETAIL NO. Depth ID OD Item 40.50' - - Tubing Hanger w/pup 1 307' 2.992 3.500 T-5 SSSV 2 2,363' 2.992 3.500 GLM 13-3/8" 3 2,415' 2.992 9.625 HS Retrievable Packer �` ` ' 2 el.- 4 2,437' 2.813 4.880 X-Nipple 3 .2 4I'S 5 2,447' 2.970 4.480 WLEG ' 6 9,601' 2.992 3.500 Top of tubing E-Line cut EICICasing 4 7 9,930' 3.00 5.968 M�51 8 Macco,3-1/2"SMO-2 GLM,1-1/2",RK w/OGLV installed Damage .- 5 8 9,950' - - CIBP 2,480'-3,420' ' 9 10,012' 3.06 4.500 HES, No-Go Seal Assembly,10',Molded Cell:aa Vr 10 10,009' 4.00 8.120 HES,9-5/8",36#-59.4#,'BWD'Permanent Packer S€"v' 11 10,013' 4.00 5.020 HES,Seal Bore Extension, 8'Long - 12 10,021' 2.992 5.720 HES,Tubing Adapter stage 13 10,032' 2.813 3.970 HES,'X'Nipple,2.813 Colla 7,077 14 10,041 2.992" 6.030 WLEG - -6 Fish: MD y 8 + 10/22/1993 2.74"O.D.Overshot&Rope Socket,15"Long Disconnect,XO,2-3/8" 9 Drillex Motor,2.625"Wash Pipe and Shoe -----><--- ><:.f 09/28/1986 32'of 2-5/8"Perf Gun top at 10,502' / 9 104P► icOc1 j 1!1 11 12 Perforation History in 13 Zone Top(MD) Btm(MD) Top Btm Amt Condition Date �i 14 (TVD) (TVD) G-2 10,240' 10,275' 8,770' 8,799' 35' Isolated 03/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Isolated 03/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 03/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/01/1990 9-5/ TD=10,630" PBTD=10,593' Updated By:JLL 11/11/14 Max Angle=38.6°@ 4,917' McArthur River Field, TBU , B PROPOSED Well: D-31RD • Completed: 10/11/2014 Harorp Alaska,LLC CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 H-40 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' RKB=40.5' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' F 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' �J 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing 3-1/2" 9.2# L-80 Supermax 2.992 Surf 2,446' 20" 1 3-1/2" 9.2# L-80 Butt SC 2.992 9,601' 10,012' JEWELRY DETAIL NO. Depth ID OD Item 40.50' - - Tubing Hanger w/pup 1 307' 2.992 3.500 T-5 SSSV 2 2,363' 2.992 3.500 GLM 13-3/8" 2 3 2,415' 2.992 9.625 HS Retrievable Packer s 4 2,437' 2.813 4,880 X-Nipple 3 5 2,447' 2.970 4.480 WLEG 6 9,601' 2.992 3.500 Top of tubing E-Line cut rgi 47 9,930' 3.00 5.968 McMurry Macco,3-1/2"SMO-2 GLM,1-1/2",RK w/OGLV installed Casing 11/25/08. Damage I_____A 5 8 9,950' - - CIBP 2,480-3,420' 9 10,012' 3.06 4.500 HES, No-Go Seal Assembly,10',Molded 10 _ 10,009' 4.00 8.120 HES,9-5/8",36#-59.4#,'BWD'Permanent Packer 11 _ 10,013' 4.00 5.020 HES,Seal Bore Extension, 8'Long _ 12 10,021' 2.992 5.720 HES,Tubing Adapter Stage Collar@ 13 10,032' 2.813 3.970 HES,'X'Nipple,2.813 7,077' - 14 10,041 2.992" 6.030 WLEG 6 Fish: 1b13"- 10/22/1993 2.74"O.D.Overshot&Rope Socket,15"Long Disconnect,X0,2-3/8" 8 Drillex Motor,2.625"Wash Pipe and Shoe 09/28/1986 32'of 2-5/8"Perf Gun top at 10,502' 10 ii X12 Perforation History IA( 13 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Condition Date GGS SZ10 ±2,640' ±2,521' ±2537' Future 14 GGS SZ11 ±2,760' ±2,627' ±2,636' Future G-2 10,240' 10,275' 8,770' 8,799' 35' Isolated 3/31/1998 G-3 10,310' 10,338' _ 8,829' 8,853' 28' Isolated 3/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Isolated 3/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Isolated 10/1/1990 9-5/2 TD=10,630" PBTD=10,593' Updated By:JLL 08/31/15 Max Anala=3R R' 4 917' Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, September 02, 2015 10:00 AM To: Schwartz, Guy L (DOA) Subject: RE: D-31RD (PTD 176-074) Perf sundry Attachments: RE: D-31rd Sundry 314-367, PTD 176-074 That is absolutely correct sir—CIBVis still in place isolating oil sands We tried cement squeezing multiple times over the course of a week but could not seal up the high pressure gas completely. This is why instead of a kill string we ran the completion with the packer and SSSV so we could blow down the problem interval. I have attached the discussion we had a year ago under sundry 314-367 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: September 02, 2015 9:50 AM To: Dan Marlowe Subject: D-31RD (PTD 176-074) Perf sundry Dan, Assume that the CIBP is still in place at 9950'? (can't commingle production) Can you refresh memory on previous workover? Did you ever cement sqz the casing damage area? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.aov). 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other Q Run Gas Lift Performed: Alter Casing ElPull Tubing El Stimulate - Frac ❑ Waiver ElTime Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development I] Exploratory ❑ Stratigraphic❑ Service ❑ 176-074 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20215-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 Trading Bay Unit / D-31 RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Middle Kenai Oil Pool 11. Present Well Condition Summary: ECEIVE Total Depth measured 10,630 feet Plugs measured 9,950 feet A NN 12 2014 true vertical 9,103 feet Junk measured 10,502 feet A�h)(�+�[/�'l�, ° • `�^ v �+ Effective Depth measured 10,593 feet Packer measured 2,415'& 10,009' feet _ true vertical 9,071 feet true vertical 2,317' & 8,575' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 718' 20" 718' 718' 1,530 psi 520 psi Surface 2,492' 13-3/8" 2,492' 2,387' 3,090 psi 1,540 psi Intermediate Production 10,630' 9-5/8" 10,630' 9,103' 5,750 psi 3,090 psi Liner Perforation depth Measured depth 10,240'- 10,426' feet True Vertical depth 8,770'- 8,928' feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 2,446' (MD) & 10,012' (MD) 2,345' (TVD) & 8,577' (TVD) HS Retrievable Packer 2,415' (MD) 2,317' (TVD Packers and SSSV (type, measured and true vertical depth) HES Perm. Packer 10,009' (MD) 8,575' (TVD) T-5 SSSV 307' (MD) & 307' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2,480' - 3,420'. Treatment descriptions including volumes used and final pressure: See attached operations summary. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1100 1064 Subsequent to operation: 0 0 0 392 108 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-367 Contact Dan Marlowe Email dmarlowel-hllcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature 419 Phone (907) 283-1329 D Form 10-404 Revised 10/2012 ,1.1q.tt ,0001OV, ate 11/12/2014 FIBC MS NOV 132 Submit Original Only 0 Hik-p Ala+ka. LLC RKB = 40.5' TD =10,630" PBTD =10,593' Max Angle=38.6° @ 4,917 :+ SCHEMATIC McArthur River Field, TBU Well: D-31RD Completed: 10/11/2014 CASING AND TUBING DETAIL S17F WT (;RADE CONN ID TOP BTM. 20" 94 H-40 - 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing 9,930' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM ,1-1/2", RKw/ OGLV installed 11/25/08. 8 9,950' 3-1/2" 9.2# L-80 Supermax 2.992 Surf 2,446' HES, No -Go Seal Assembly, 10', Molded 10 10,009' 4.00 8.120 HES, 9-5/8", 36#-59.4#,'BWD' Permanent Packer 11 3-1/2" 9.2# L-80 Butt SC 2.992 9,601 10,012' JEWELRY DETAIL NO_ Denth ID OD Item Fish: 40.50' - - Tubing Hangerw/pup 1 307' 2.992 3.500 T-5 SSSV 2 2,363' 2.992 3.500 GLM 3 2,415' 2.992 9.625 HS Retrievable Packer 4 2,437' 2.813 4.880 X -Nipple 5 2,447' 2.970 4.480 WLEG 6 9,601' 2.992 3.500 Top of tubing E -Line cut 7 9,930' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM ,1-1/2", RKw/ OGLV installed 11/25/08. 8 9,950' - - CIBP 9 10,012' 3.06 4.500 HES, No -Go Seal Assembly, 10', Molded 10 10,009' 4.00 8.120 HES, 9-5/8", 36#-59.4#,'BWD' Permanent Packer 11 10,013' 4.00 5.020 HES, Seal Bore Extension, 8' Long 12 10,021' 2.992 5.720 HES, Tubing Adapter 13 10,032' 2.813 3.970 HES, 'X' Nipple, 2.813 14 10,041 2.992" 6.030 WLEG Fish: 2.74 O.D. Overshot & Rope Socket,15"Long Disconnect, X0, 2-3/8" 10/22/1993 Drillex Motor, 2.625" Wash Pipe and Shoe 09/28/1986 32' of 2-5/8" Perf Gun top at 10,502' Updated By: AL 11/11/14 Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btrn (TVD) Amt Condition Date G-2 10,240' 10,275' 8,770' 8,799' 35' Open 03/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Open 03/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Open 03/31/1998 G-4 10,418' 10,426' 8,921' 8,928' 8' Open 10/01/1990 Updated By: AL 11/11/14 Now Hilcorp Alaska LLC Well Operations Summary Well Name DAPI Number I Well Permit Number I start Date I End Date R/U CIRCULATING EQUIPMENT. SITP=1200 PSI SICP=1200 PSI DISPLACE WELL DOWN CASING TAKING RETURNS UP TUBING TO PRODUCTION W/8.5# F.I.W. @ 4 BPM STARTING PRESSURE = 1200 PSI AFTER 300 BBHLS PUMPED PRESSURE = 750 PSI FINALL CIRCULATING PRESSURE = 650 PSI WIT 700 BBLS PUMPED. CLOSE WING VALVE ON TREE AND BULL HEAD 90 BBLS OF FIW @ 4 BPM 750 PSI. SHUT DOWN PUMP -0 AND BLEED OFF CASING AND TBG TO -0- PSI. SHUT IN SAME AND PRESSURE BUILT TO 100 PSI IN 5 MIN. SHUT WELL IN. At 06:00 hrs tbg pressure = 240 psi Cont. to prep rig to skid to D-31RD. N/U Coil TBG 4.5 X 10M Riser & BOP'S On Well D-31RD. Secure Stack. Hook Up Hoses to Stack. Function Test Rams & Hook Up Pump Lines. Test Schlumberger Coil BOP'S 250 psi Low & 2500 psi High. Held Each Test On Chart For 5 Min. Witness of test waived by Jim Regg, AOGCC. Perform General Rig Maintance & Clean Rig. M/Up Wash Nozzle Assy Pull Test 20K. P/U Injector Head, Test Surface Line 2500 psi. RIH W/Coil To 6,000'. RIH Washing @ 50 FPM In 500' Intervals. Circ 15 bbls Each Interval To 7,768'. Started Taking More Wt. To Wash. Circ Out Getting Back Sand & Scale @ Shaker. Once Cleared Up, Cont. Washing @ 40 FPM In 250' Intervals Pumping 20 BBLS @ 1.24 BPM 3800 PSI. Cont. Washing To 9,710' Tag 4K Down. Work Coil F/ 9,200' To 9,600', While Circ. Well Clean @ 1.35 BPM W/ 3200 PSI. Cont. Washing F/ 9,710' To 9,875' In 50' Intervals pumping 10 BBLS @ 1.5 BPM 3650 PSI. Broke Thru Bridge @ 9,875', Lost P/ Returns. Cont. Washing F/ 9,875' To 9,980'. ( Max Drag @ 9,980' 28040#) P/U & Pump 38 BBLS NW50 Pill, While Working Pipe F/ 9,600' TO 9,700'. Once Pill Out Coil @ 9,700'. POOH @ 150' Min Slow Pump Rate Down To 1/2 BPM W/ No Returns. Secure Well R/D Injector Head. R/U Slickline & Lubricator, Test Lubricator To 2500 PSI. Rig Down Wire Line. Move Misc. Equip. And Rig Up E- Line Equip. M/U Lubricator And 2.50" CIBP. Test Lubricator 2500 PSI. (OK). Open Well 800 PSI On TBG, 1010 PSI On 5/8" 47# CSG. RIH Set CIBP At 9,950'. POOH W/ E -Line. M/Up 11/16" TBG Puncher. RIH W/ Same To 9,600', POOH W/ 11/16" TBG Puncher. Did not Fire. Reload 11/16" TBG Punch, RIH W/ 11/16" TBG Puncher To 9,600' And Shot 5 Holes In TBG At 9,600'. POOH W/ E -Line And R/D E -LINE Lubricator & Equip. Rig up injector head, fluid pack and test breaks 250 psi and 2500 psi bleed pressure down to 1050 psi, open well SITP 998 PSI & SICP 1080 PSI. RIH w/ coil to 9,540 ft. displace 8.5 ppg fluid w/ 9.5 ppg pump 42 bbls pooh while pumping 9.5 ppg stopping at 2000 ft. ctm. Continue pumping 9.5 ppg at 1.3 bpm 3868 psi w/ 250 psi on choke with 9-5/8 csg pressure at 1229 psi. Pumped a total of 150 bbls before getting 9.5 ppg fluid back to surface. Pooh with coil, rig down injector and set aside. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 r s F et 09/05/14 - Friday Cont. POOH W/ Coil TBG. & Bleed Off TBG. R/D Injector Head & Set Aside & Secure Same. R/U Circ. Lines To Circ. Out 9 5/8" 47# Csg. SICP 1160 PSI. Pump Down 3 1/2" TBG. Taking Returns 9 5/8" 47# Csg. Thru Choke To Prod. Pumping @ BPM @ 130 PSI Holding 160 psi On Choke. Got Gas back @ 115 BBLS Pumped. Getting Gas & Oil Mix @ 140 BBLS. Got 9.0 ppg Back, W/ 175 BBLS Pumped had 9.5 back. Pump Total Of 200 Of 9.5 PPG Fluid. Shut Down Pumping Monitor SICP = 30 PSI, SITPO, TBG Increase To 130 PSI & SICP INCREASE To 135 PSI. Wt Up Surface Vol. F/ 9.5 To 9.9 PPG. Rig Up Injector & Test Lubricator & Line To 250 PSI Low & 2500 PSI High, Held Each Test 5 Min. "OK". RIH W/ Coil TBG To 9,500'. Displace 9.5 ppg fluid w/ 9.9 ppg pump 42 bbls pooh while pumping 9.9 ppg stopping at 2700 ft. ctm. Continue pumping 9.9 ppg at 1.3 bpm 2868 psi w/ 200 psi on choke with 9-5/8 csg pressure at 296 psi. Pumped a total of 180 bbls before getting 9.9 ppg fluid back to surface. Close Choke & Bull Head 30 bbls NW50 Pill @ 1.3 BBLS Min. W/ CSG Pressure @ 433 PSI & TBG Pressure @ 371 PSI. POOH W/ Coil TBG. & R/D Injector Head & Set Aside & Secure Same. R/U Circ. Lines To Circ. Out 9 5/8" 47# Csg. SICP 80 PSI. Pump Down 3 1/2" TBG. Taking Returns 9 5/8" 47# Csg. Thru Choke To Prod. Pumping @ 2 BPM @ 212 PSI Holding 180 psi On Choke. Got Back A Trace Of Oil W/ 9.4 ppg Fluid @ The Beginning Then The Fluid Cleared Up. Got 9.9 ppg Back W/ 172 BBLS Pumped. Pump Total Of 197 Of 9.9 PPG Fluid. Shut Well In & Monitor TBG & Csg. Press. Shut In Csg Press 60 PSI & TBG Press 80 PSI. 0300 hrs SITP 15 PSI SICP 50 PSI, 0400 HRS SITP 1 PSI SICP 40 PSI, 0500 SITP 0 SICP 34„ AT 0600 SITP 0 sicp 30. 09/06/14 - Saturday Perform General Rig Maintenance & Clean Pump Room While Monitoring Well. 9 5/8" CSG - 30 PSI, TBG - 0 PSI. Bled Down Surface Lines To - 0 PSI. Arrange Circ. Lines. Install Injector Head On BOPS Test Break 250 PSI Low & 2500 PSI High. Transfer 70 BBLS Of 9.9 PPG Fluid F/ SLB Tank To Rig Tank. HPJSM Pump Nitrogen & Blow Down Coil TBG. Back To Shaker Tank. R/D Coil TBG. Equip. & Prep. To Load Out. (9 5/8" CSG Pressure @ 1800 HRS. - 0 PSI. Finish R/D SLB. & L/O Same On The Resolution & Champion Work Boat. ( 9 5/8" CSG & 3 1/2" Prod. TBG Had - 0 psi @ 24:00 HRS. Separated PZ - 9 To Be Able To Move. Clean Top Deck. Clean Gas Buster. Move Equip. Preparing For Load Out Of Old Pipe Rack Deck. Move Equip. Around Below Deck. Preparing For New Pipe Rack Deck.( 9 5/8" CSG. & The 3 1/2" Prod. TBG Had - 0 PSI & The 13 3/8" CSG. Had 300 psi On Gauge @ 04:00 HRS. 09/07/14 - Sunday; Continue To Clear Old Section Of Pipe Rack & Load Out Pipe Rack Onto Work Boat. Open Well SITP 110" SICP 110". CIRC 9.9 PPG Fluid Down TBG Taking On Return From 9 5/8" Csg Valve @ 2 BPM 150 PSI ON TBG W/ 145 PSI On Choke, Took 16 BBLS Before Getting Returns. Pump Total 187 BBLS Of 9.9 PPG Fluid Before Getting 9.9 PPG Fluid Back. Low Fluid Cut 8.8 PPG. Shut Down Pump, Monitor Well. 43 PSI On TBG & 60 PSI On CSG. Monitor For 1 HR. No Build Up. Bled Pressure To "0" & Monitor Same. Continue To R/D, Pump & Electric Lines To Make Shuffle Off Pipe Rack. Cleaning shaker tank and pulling shaker from pipe rack, prepare to change out shale shaker. Clean and move return tank to remove shaker, rig down pumps, rig down middle section of pipe rack and load out same onto boat. Move 20' section of pipe rack to north end. Move PZ9 pump to south end of pipe rack. Remove shaker from return tank. 3 1/2 prod tbg OPSI, 9 5/8 csg OPSI, 13 3/8 csg 190PSI, 30% rigged up. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 09/08/14 - Monday Removed Agitators From Shaker Tank. Prepare Active Tank To Install Agitators. Clean Platform & Rig Equip. Perform Preventive Maintenance On Mud Pumps & Misc Rig Equip. Rig Up The 2-Mud Pumps & Pump Motor @ The End Of The Platform. SITP "0" SICP "0" 13-3/8 ( 290 PSI ). 09/09/14 -Tuesday Spot Toolpusher Office In Place. Move Pipe Rack To South Side Of Platform. Prep To Install # 2 Agitator In Active Tank. Off Load Pipe Rack Wind Wall For Second Section & R/U Same. Put Up Brace For Third Section. Put Up East Wind Wall For The Third Section & Wind To Strong To Put Up West Side W/ Crane. Installing Agitators On # 2 Mud Pit. Put Belts & Guard On PZ - 9 Mud Pump & Tighten Same. Off Loaded Work Boat, Set Second Pipe Rack In Place, Set Third Pipe Rack On # 2 Pipe Rack. Finish Installing Agitators On Mud Tank. Lift Shaker Tank W/ Crane Put 6" 1 Beam Under Tank Skid & Welded Same. Added New Shaker To Shaker Tank. Put BOP Stump In Place. 09/10/14 ' Wednesday - Finish Setting Side Wall & Line Up Same W/ Skid Beams. Set Top Decks In Place Line Up Same. Install Bolts Start Drilling Holes In New Section. Run Electrical Wires To Agitators & Lights. Plumb Mud Pump. Skid Shale Shaker Tank Next To Mud Tank. Assist Welder Make Walk Way For Mud Tanks & Set Steps For Suction Tank. Hanging Brackets Up On Pipe Racks & Hanging 6" Stiff Lines In Same F/ Gas Buster To Shaker Tank. Tying 4" & 2" On Brackets Above 6" Line F/ Gas Buster To Choke Manifold . Assist Crane Off Load Work Boat. Install Walk Way F/ Pipe Rack To Driller Shack Added Hand Rails To Same. Cut Covers To Fit Wire Tray & Install Same. Stacking bop's and setting same on stump. SITP "0" SICP "0" 13-3/8 CSG ANNULUS 280 psi. 09/11/14 - Thursday Continue running wiring for lights, agitators, and mixing pump. Fabricate return line from gas busted to shaker, mixing 100 bbls of 9.9 ppg. R/U SL w/ full lubricator. M/U 13/4" tool string (rope socket, swivel, stem x 2, long spang jar & 3" tb i.d. brush on .125 alloy wire)- pulled inside lubricator and pressure tested w/ 9.9# SW to 2500#s. Opened well and RIH w/ brush to 290'- worked brush 20+ times from 290' to 35' pumping 20 bbls of 9.9# SW at 2 BPM max pressure was 70#s. POOH and B/0 brush. M/U AD2 Stop on GS Running Tool. RIH and set stop at 201'. POOH and redressed running tool. M/U D&D packoff plug and RIH- set same on stop at 201'. POOH and redressed running tool. M/U AA Stop and RIH- set same on plug @ 200'. POOH and R/D SL. Unbolt 2 1/2" Bowen lubrication connection and flange up tree top connection. Cameron installed BPV. N/D tree and broke down tree where it would pass thru opening in deck. Cleaned and checked hanger threads with 4 1/2" 8rd sub. N/U riser and wing valves. Note: Mr. Lou Grimaldi is schedule to be at Heliport NOON to come out and witness BOP TEST. SITP "0" SICP "0" 13-3/8 ANNULUS 280 PSI. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 1 176-074 6/28/14 10/11/14 09/11/14,-, Friday Continue to stack 11" 5M bop & bell nipple torque bolts on same. Install choke & kill lines. Hook up Koomey lines. Install beams & floor plate on work platform align & secure BOP stack. Install hand rails around bop's. Make up test equipment. Pull BPV, install two way check. Make up test plug and test jt. Fill stack and surface equipment attempt to preform shell test no success, riser leaking, retighten same. Test 11" 5m bops' surface equipment to 250 / 2500 psi as per AOGCC & HILCORP specs to 200 low and 2500 psi hi. Good test on pipe rams, 2-way check, safety valve, inside and outside wings but tests failed when we went to choke manifold. Worked thru sequences with multiple failures. Greased (w/ heavy duty Moly 5% grease) and worked valves. Retested with same results. Consulted with production and regreased valves with special duty grease. Retested manifold with same results- multiple. AOGCC rep departed location at 2145 hrs- requested that we notify him once we have a good test. Broke apart#4 WKM 2 1/16" gate valve, found damaged teflon seat (— 1/4" piece gone). Removed #4 from manifold and installed blind flange to continue determining bad valves. Lou Grimaldi with AOGCC onboard at 1200 to witness BOP Test. Departed rig at 2145 while making repairs to choke manifold. 09f 13j14 "Saturday_ Removed valve from #1 choke manifold. Hooked up pump flange & attempt to test remaining valves - with no luck. Rig down choke manifold house & lay choke manifold on deck & disassemble choke manifold, 6 of the replacement valves & bolt up same. Two remaining valves arrived at 1445 hrs. N/u remaining valves & torque bolts. AT 0930 hrs to 1530 hrs tested the circ manifold to 200 psi low & 2500 psi hi, notified AOGCC Mr. Lou Grimaldi of progress by E-mail. Shell tested choke manual to 2600#s on deck- tighten one leak and retested before mounting in carrier- good test. Mounted manifold and moved it into position- hooked up all service lines and filled stack- lined up same to test. Tested all choke manifold valves and lines @ 250#s low/ 2500#s high (as per AOGCC guidelines)- charted and held for 5 mins. Performed accumulator draw down test as per AOGCC guidelines. Notified AOGCC (Mr. Lou Grimaldi) concerning results and received permission to carry on (witness waived). Backed out test joint and pulled 2-way check. P/U slickline lubricator and screwed into hanger, test lubricator to 2500 PSI. R/U S/L to pull stop at 200'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 w 09/14/14 - Sunday Continue rigging up and space out slick line, rigging up lubricator and test same to 2500 psi. Made 3 run w/ slick line pulling the AA stop and pack off plug & A2 stop at 200 ft SLM. Rig down slick line, fill hole w/ 9.9 ppg fluid filled pipe w/ 3 bbls getting return w/ 15 bbls pumped. Rig up E-line test lubricator to 2500 psi made up 2.5 chemical cutter, Rih correlate on depth with top GLM at 2510 ft. spot and made cut at 3040 ft. Pooh rig down E-line. Worked and pull hanger free w/ 74k had to work same several times, pull hanger to floor with no problems, demo control line and lay out hanger = 9.31' (hanger, xo & pup). Made up circ lines and circ hole w/ EOT AT 3,000 ft. at 1.5 bpm at 70#s psi. Increased pump rate to 2 BPM 210#s psi. Circulated one hole volume (9.9# SW down tb- 218 bbls) and shutdown pumps- well flowing on both sides. Circulated 2nd hole volume (down tb) and shut down pumps- still flowing on both sides. Lined up to circ down annulus and pumped 3rd hole volume- tb on slight vacuum- well settled. Lost — 30 bbls total. Broke off safety valve and pulled 6 jts of 3 1/2" BTC production tb + hardware (total = 201.53') OOH. Put protectors on and strapped pipe- checked for NORM (0 reading). Installed safety valve and Kelly hose- @ 2,795' pumped 15 bbl NW50 pill followed by 22 bbls 9.9# SW. Opened well with minimal utubing- well static. B/O Kelly hose and safety valve- continued pulling recovered 3 1/2" production string OOH. 1,156' laid down at report time. 09/15/i4'-'Monday', Continued POOH with recovered 3 1/2" 9.2# BTC production string- recovered 94 jts, six pups, SSSV, hanger, cut jt & all control line = 2,999'. Found hole in jt #85. Cleared and cleaned rig floor- broke pup off hanger. M/U BHA #1 (8 1/8" OVS Idd w/ 3 1/2" basket grapple, MCPO and 2 1/4" stop)- make same up on a single jt of workstring. TIH w/ 3 1/2" 12.95# PH6 workstring and ovs (picking up off rack rabbiting and strapping) to 3,041'- latched fish and pulled to string wt of 107k then pulled an additional 20k that with be needed to FP with. R/U EL w/ full lubricator- tested same to 1000#s. Run #1 TIH w/ 1" Applied FP tool + ccl & 1.70" wt bars x 2 to 3,230'- could not get deeper- POOH. Run #2 TIH w/ 13/4" bailer + spang jars, knuckle & 1.70" wt bars x 2- bailed to 3,331'- POOH- recovered iron sulfide (1/2 bailer full). Run #3 TIH w/ same tool string and bailed to 4,010'- POOH- recovery same. Run #4 TIH w/ same tool string and bailed to 4,011', POOH w/ bailer- full bailer of same material. Run #5 TIH with freepoint tool. 09/16/14 -Tuesday TIH w/ Eline 1" FP tool to take reading- 100% free at 4,011' (could not get deeper). POOH and rigged EL unit to side. Position and R/U SL unit- M/U 2" bailer w/ spang jar, knuckle & wt bars- pulled inside lubricator and tested same to 2500#s. TIH to 4,011' and bailed to 4,087' (8- runs) . M/U 13/4" bailer and TIH to 4,087' bailed thru bridge- stopped at 7,344' and POOH. M/U 2" bailer and tripped in hole to 9,617- decision was made to not go deeper because off possible cork-screwed tb- POOH. M/U 2" gauge and TIH to 9,845'- tagged- could not get deeper. POOH and R/D slickline. R/U EL unit w/ full lubricator- M/U 1" FP tool w/ ccl & 1.70" wt bars x 2- pulled tools inside lub and M/U to string- tested lub to 2000#s. TIH to — 1000' and tool was not working properly. POOH and change to 13/8" FP. TIH and took readings at 6,625', 7,500', 8,892' & 9,756' 100% free- could not get deeper than 9,832'. POOH and rigged EL to side. Rigging down lubricator on E-Line. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 1 176-074 6/28/14 10/11/14 t 09/17/14- Wednesday' Continued R/D EL lubricator and equipment. R/U circ equipment and broke circulation down tubing taking returns up annulus to rig tank. Displaced well @ 2 1/2 BPM 400 PSI w/ 9.9# SW, taking returns to rig tank until light fluid at surface. Lined up returns to Trading Bay and continued displacing well @ 11/2 BPM 350 PSI w/ 9.9# SW until returns were 9.9# SW. Total pumped 680 bbls. R/D circ equipment and P/U pipe to 130k- set same on slips. R/U EL equipment and lubricator. M/U 2" RTC and pull inside lub. M/U to string and test lubricator to 2500#s. RIH to 9,834' and correlate on depth. Fired cutter @ 9,784' (ELM)- no surface indication of cut. POOH to check cutter (fired). Rigged EL to side. Latched on to pipe and attempted to pull cut- working pipe from 45k to 150k- would not pull free. Set pipe on slips at 130k. P/U EL lubricator- M/U 2nd RTC. Pulled inside lub and M/U to string- tested to 2500#s. TIH to 9,601' and fired cutter- tool was blown up hole and stuck at 9,561'. Worked line from 1000#s to 2200#s till WL cutting tools arrived onboard. Worked EL to 3200#s in effort to pull out of rope socket and succeeded after 20 mins. POOH and found that we had pulled out at RS. R/D EL equipment. R/U SL unit w/ Bowen lubricator. M/U 2.125" Bowen Ovs w/ shear down pulling tool + spang jars, stem & knuckle- pulled inside lubricator and tested same to 2500#s. TIH and tagged at ovs @ 3,040'- could not get thru 2 1/4" stop in ovs- POOH and B/0 tools. M/U 11/4" JDC pulling- TIH. FLUID LOST TODAY 0 BBLS ---- TOTAL FLUID LOST 30 BBLS. 09/18/14 - Thursday Continue RIH (Run #2) w/ 11/4" JDC pulling tool w/ 2" bell guide to 9,532' (SLM)- could not latch fish- POOH. B/O tools and M/U 17/16" OVS (Run #3) TIH and latch EL RTC tools- took overpull and ovs would slip off — 1800#s every time (could not maintain bite). POOH and B/O tools. M/U 2.21" guide and changed grapple- RBI hole- could not latch fish. POOH and B/O tools. M/U 13/4" ovs w/ 2.12" centralizer, latched fish and took overpull- ovs would slip off at @ 1800#s every time. POOH and B/O tools- standby for needed grapple (— 1.5 hrs). MU/ RIH w/ 17/8" short catch ovs w/ 1" grapple- latched fish and took overpull- ovs would slip off @ 2800#s every time. POOH and R/D SL. Latched onto workstring and pulled (tubing free). Laid out single and installed SV. R/D a -line & removed SL sheave and hung sala block in derrick for monkey board. POOH slowly with 3-1/2" PH -6 and production tbg. B/0 & L/0 overshot with 18.71' cut jt of 3-1/2" production tbg. Continue POOH B/0 & L/O 3-1/2" IBT production tbg and GLM's cleaning and strapping same ( 130 jts & 4 GLM's = 4075' laid out ). 09/19/14 - Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH AND LAYDOWN 3-1/2" PROD TBG, STRAPPING & CLEANING EACH JT. TOTAL RECOVERED TBG, PUPS & GLM's RECOVERED SINCE W/O OPS STARTED = 9579'. CLEAR RIG AND PREP SAME TO CUT DRILL LINE. SLIP & CUT 96' DRILL LINE. RECALIBRATE & SET ALL PARAMETERS ON HMI. CHK C -O -M W/DRILL LINE. P/U OVERSHOT W/CUT PIECE AND BREAKDOWN SAME. WASH/CLEAN RIG FLOOR. M/U AND INSTALL WEAR BUSHING. LAY DOWN SETTING TOOL. P/U & M/U BHA 2 (TANDEM TAPERED MILL ASSY) 8.50' TAPERED MILL, 6.25" OD BIT SUB, 6.50" OD PONY COLLAR, 8.50" OD STRING MILL. 4.750" OD BUMPER AND OIL JARS, (4) 4.750" OD DRILL COLLARS, 3.50" PH -6 BOX X 3.50" IF PIN X -OVER. TIH W/3-1/2 PH6 AND BHA 2. TAGGED TIGHT SPOT @ 2,730' DPM. SET 25K DWN & PICKED UP & HAD 10K OVER PULL. POOH TO 2,697'. R/U POWER SWIVEL POWER PACK. P/U POWER SWIVEL & R/U SAME. CHANGED OUT DAMAGED X/O SUB ON POWER SWIVEL, MADE CONN. ROTATE AND WORK PIPE THRU TIGHT SPOT F/ 2,730'- T/ 2,760' DPM. TORQ UP TO 6800 FT/LBS. CONT' TO MAKE CONNECTIONS & TIH TO 2,790' DPM. R/D POWER SWIVEL & L/D SAME. CONT' TO TIH W/ 3-1/2" PH6 & MILL ASSY. WORKED THRU TIGHT SPOTS @ 3,219'& 3,250' DPM. P/U SINGLES F/ V -DOOR & CONT' TO TIH W/ 3-1/2" PH6. STRAPPED & DRIFTED EACH JT. DEPTH @ 06:00 = 6,500'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 - — 09/20/14 - Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT P/U 3-1/2" PH6 OUT OF V -DOOR AND TIH W/MILL ASSY. STRAP @ RABBIT SAME TO 6,831' DPM. HOLE GETTING STICKY. R/U CIRCULATING EQUIPMENT & HOSES, REV/OUT 1-1/2 DPV @1- 1/2 BPM 175 PSI, TOTAL PUMPED= 75 BBLS. CONT P/U 3-1/2" PH6 OUT OF V -DOOR AND TIH W/MILL ASSY. TO 9,535' DPM. R/U CIRCULATING EQUIPMENT & HOSES, REV OUT 2 DPV @ 1-1/2 BPM MAX PRESSURE = 215 PSI. TOTAL PUMPED =100 BBLS. RIG DOWN CIRCULATING EQUIPMENT. ( Lost 50 bbls ). POOH W/3-1/2" PH6 AND TANDEM MILL ASSY. ( HOLE NOT TAKING PROPER FILL FLUID). STAB TIW VALVE, CLOSE HYDRIL AND RIG UP CIRCULATING HEAD AND CIRCULATE W/ 9.9 PPG F.I.W. @ 2 BPM W/ 75 PSI. 104 BBLS PUMPED LONG WAY. SHUT IN @ MONITOR WELL. SIDPP=O , SICP=O. OPENED UP AND WELL STILL U -TUBING. L/U & CIRC LONG WAY @ 3 BPM. W/ 105 PSI. STARTING GETTING GAS BACK. L/U & CIRC THRU GASBUSTER. SHUT IN @ MONITOR WELL. SIDPP=O, SICP=O. CONT' TO DISPLACE WELL W/9.9 PPG F.I.W. @ 3 BPM W/ 100 PSI. 713 BBLS PUMPED LONG WAY.MAX GAS = 4900 UNITS. SHUT IN WELL SIDPP = 0, SICP = 0. OPENED UP AND WELL STILL U -TUBING. MONITOR WELL WHILE BUILDING SLUG. SIDPP = 0, SICP = 0, PUMPED A 10 BBL, 11.2 PPG NaBr SLUG & CHASED W/ 4 BBLS OF 9.9 PPG FIW. R/D CIRC EQUIP & POOH W/ 3-1/2" PHIS & MILL ASSY. 09j21/14 -Sunday . SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 AND TANDEM MILL ASSY. B/D MILL ASSY BHA AND LAYDOWN MILLS. M/U RETRIEVING TOOL AND PULL WEARBUSHING. R/U TEST JT & EQUIPMENT. SET TEST PLUG. TEST 11" X 5M BOPS & SURFACE EQUIP. AS PER HILCORP AND AOGCC SPECS. 250 LOW/2500 HIGH ON CHART FOR 5 MIN EACH TEST. TEST FROM REMOTE AND FUNCTION MAIN. PERFORM ACCUMULATOR TEST. TEST WITNESSED BY BOB NOBLE, AOGCC. PULLED TEST PLUG & L/D SAME. P/U WEAR BUSHING & R/R TOOL. RIH & SET SAME. R/D TESTING EQUIPMENT. CLEARED RIG FLOOR & PREP TO R/U E -LINE EQUIPMENT. N/U LUBRICATOR ADAPTER FLANGE ON RISER. P/U LUBRICATOR & M/U SAME. R/U E -LINE EQUIPMENT. P/U GAMMA RAY, CENTRALIZERS & CSG CALIBER TOOL PRESSURE TEST LUBRICATOR TO 1000 PSI "OK". RIH W/ E -LINE TO 9,490' WLM, ATTEMPT TO LOG UP BUT TOOL MALFUNCTIONED. POOH W/ E -LINE. TROUBLESHOOT TOOLS. CHANGED OUT XTU CROSSOVER & CLEANED BUILD UP F/ FINGERS. RIH W/ E -LINE TO 9,490' WLM & LOG UP TO SURFACE. 09/22/14 - Monday R/D E -LINE EQUIPMENT AND UNIT. M/U RETRIEVIABLE BRIDGE PLUG. TIH W/3-1/2" PH6 & CIBP TO 3,600' DPM. (100' MIN AS PER REP.) RABBIT SAME OUT OF DERRICK. SET CIBP @ 3,600' PUSH AND PULL TEST SAME. POOH TO 3,528' DPM. DUMP 25 SXS OF SAND DOWN TBG (1250#) @ 5 MIN PER SACK. ESTIMATED TOP OF SAND @ 3,580' DPM. R/U CIRC HOSE AND DISPLTBG 1 TBG VOL. W/9.9# FIW @ 1 BPM 75 PSI TOTAL PUMPED =26 BBLS. POOH W/3-1/2" PH6 AND SETTING TOOL. WELL STARTED U -TUBING, REV / OUT 1 TBG VOL 2 BPM 150 PSI . MONITOR WELL. WELL U -TUBING. SERVICE RIG WHILE BUILDING SLUG. PUMPED 6 BBLS OF 10.9+ PPG NaBr SLUG & CHASED W/ 3 BBLS OF 9.9#. CONT' POOH W/ 3-1/2" PH6 & SETTING TOOL. L/D SAME. P/U RTTS PKR & RUNNING TOOL. TIH W/ SAME TO 2,730' DPM. P/U=35K, S/0=33K. R/U CIRC EQUIP. & PREP TO TEST CSG. SET PKR & 2,730' DPM SET 23K DOWN. PRESSURE UP DOWN TBG 2500 PSI & HELD FOR 10 MINS. L/U& PUMP DOWN BACKSIDE. ESTABLISHED INJECTION RATES. 1 BPM = 190 PSI, 2 BPM = 350 PSI, 3 BPM = 440 PSI, RELEASE PKR & POOH TO 2,650'. SET PKR & SET 23K DOWN. PUMPED DOWN TBG @ 3 BPM W/140 PSI. INJECTED 3 BBLS. L/U & PRESSURED UP ON CSG TO 2500 PSI AND HELD FOR 10 MINS. RELEASED PKR & WORKED DOWN HOLE TO LOCATE HOLES. HOLES BETWEEN 2,671' - 2,730' DPM. R/D CIRC EQUIP. POOH W/ 3-1/2" PH6 & RTTS PKR. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 31 09/23/14 -Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. M/U 3.50" MULESHOE AND TIH W/3-1/2" PHIS TO 2,707' DPM. CONSULT W/HILCORP ENGINEER ON CEMENT JOB. POOH TO 2,616' DPM. R/U HALIBURTON CMT EQUIPMENT TO RIG FLOOR. TEST LINES TO 3000 PSI. BREAK CIRCULATION & EST. INJ. RATES,1 BPM 70 PSI, 2 BPM 250PSI & 3 BPM 380 PSI. HALIBURTON MIX & PUMP 10 BBL 9.9# FIW SPACER, 25 BBL 15.8# CLASS "H" CMT, 5 BBL 9.9# SPACER AND DISPLACE W/20 BBLS 9.9# FIW. FINAL INJECTION PRESSURE= 475 @ 1 BPM. R/D HALIBURTON IRON FROM RIG FLOOR. POOH 5 STDS TO 2,308' DPM. R/U CIRCULATING EQUIPMENT AND REV/OUT 2 DPV @ 90 PSI, TOTAL PUMPED=34 BBLS. MONITOR WELL. PRESSURE UP TO 200 PSI ON CSG,TOTAL PUMPED = 1 BBL. BLEED OFF PRESSURE NO SUCCESS, WELL U -TUBING. REV/OUT @ 2BPM 140 PSI, TOTAL PUMPED = 150 BBLS HAD -0- GAINS OR LOSSES WHILE REVERSING. SHUT IN WELL HOLDING 160 PSI ON CSG AND MONITOR WELL. 30#s ON WELL AFTER 8 HRS. OPENED WELL AND PUMPED 4 BBLS FIW WITH INJECTION RATE OF 11/4 BPM 220#s. SHUTDOWN PUMP AND FLOWED BACK 4 BBLS- WELL STATIC. R/D CIRCULATING EQUIPMENT AND RAN IN 5 STANDS = 2,616'. INSTALLED SAFETY VALVE. HELD PJSM W/ JSA W/ RIG AND CRANE CREW + HALLIBURTON CREW. R/U HALLIBURTON CIRCULATING EQUIPMENT AND PRESSURE TESTED LINES TO 3000#s. OPENED WELLAND EST INJECTION RATE AT 280#s 1 BPM- PUMPED 10 BBL FIW SPACER W/ FINAL PRESSURE OF 500#s 2 BPM + 25 BBL 15.8# CLASS'H' CMT + BBL FIW SPACER AND DISPLACED WITH 19 BBLS FIW. FINAL INJECTION PRESS OF . MONITORED PRESSURE FOR 10 MINS = 487#s. BLED OFF PRESSURE AND R/D HALB CIRC EQUIP. PULLED 7 STANDS AND R/U CIRC EQUIP. REVERSED 2 DPVs AND MONITORED WELL- 30#s INITIALLY- AFTER 30 MINS PRESSURE INCREASED TO 70#s. WAITING ON CEMENT - MONITORING PRESSURE. 09/24/14 - Wednesday MONITOR WELL WHILE WAITING ON CMT. INITIAL SICP=30 PSI. CONTINUE WINTERIZING MISC RIG EQUIPMENT. PRESSURE TO 500 PSI# @1/2 BPM AND TEST CMT PLUG "OK". POOH W/ 3-1/2" PH6 AND MULE SHOE. M/U 8.50" BIT AND (4) 4-3/4" DC'S, TIH W/ 3-1/2" PH6 AND BIT ASSY. TAGGED UP AT 2,514'. LAID DOWN 10 SINGLES TO USE DRILLING CMT AND RAN IN 4 STANDS. N/U ADAPTER FLANGE W/ STRIPPING HEAD. P/U POWER SWIVEL W/ SINGLE + RUBBER- M/U TO STRING AND LANDED RUBBER. ESTABLISH PARAMETERS: 38K P/U, 34K S/0, 1500-2300 FPT @ 70 RPMs, 2 BPM @ 260 PSI (HAD TO CHANGE FRONT SCREEN SIZE TO EFFECTIVELY DRAIN RETURNS). DRILLED CMT FROM 2,514' TO 2,680' CIRCULATING IN REV TILL RETURNS CLEANED UP (EVERY 30'). TOTAL OF 9.5 BBLS OF CMT DRILLED OUT. SHUTIN WELL AND BEGAN 1500# TEST- BROKE DOWN AT 400#s- PUMPING IN AT 220#s @ 1 BPM. R/D POWER SWIVEL AND N/D ADAPTER W/ STRIPPING HEAD. POOH W/ 8 1/2" VAREL BIT & COLLARS. RACKED BIT ASSEMBLY BACK- TO BE USED LATER. M/U 3 1/2" PH -6 MULE SHOE ON WORKSTRING AND TIH TO 2616'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 09/25/14,- Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/ 3-1/2" PH6 AND MULE SHOE TO 2616' DPM. FINISH CLEANING OUT MIXING PIT AND R/U HOSES TO MIX 20 BBL POLY PLUG. PERFORM GENERAL RIG MAINTENANCE AND HOUSEKEEPING WHILE WAITING ON POLY PLUG MATERIAL TO ARRIVE FROM DOCK. MIX 20 BBL PLUG AS PER PROCEDURES, DISPLACE POLY PLUG TO END OF TBG @ 2BPM 190 PSI. SHUT CIRCULATING AND SQUEEZE 20 BBL POLY PLUG W/ 24 BBLS 9.9# FIW @ 1/2 BPM 800 PSI. SHUT IN WELL & MONITOR WELL, PRESSURE BLED TO 650, BUMP BACK UP TO 850 (2) TIMES, PRESSURE KEPT BLEEDING OFF- FINAL PRESS= 650 PSI. EST INJ RATES W/RIG PUMP, 1 BBL 650 PSI, 2 BBLS 800 PSI & 3 BBLS 940 PSI. MIX AND PUMP 7 BBL SPACER, 20 BBLS 15.8# CLASS "H" CMT AND 5 BBL SPACER, DISPLACE W/ 19.2 BBLS. FINAL INJECTION PRESSURE, CSG PRESSURE 900 PSI, TBG PRESSURE 700 PSI @ 1 BPM- BLEED OFF PRESSURE AND R/D IRON FROM RIG FLOOR. POOH TO 2186' DPM, REV OUT 2 TBG VOLS @ 3 BPM 178 PSI. SHUT IN WELL W/ 275 PSI. TOTAL PUMPED = 34 BBLS. WAITING ON CEMENT. CLEAN AND ORGANIZE RIG FLOOR, PUMP ROOM AND DECKS. MOVED SOLIDS MAKING ROOM FOR NEXT DRILL OUT. PRESSURE UP TO 500 PSI ON CASING AND HOLD SAME FOR 30 MIN, POOH WITH 3-1/2" WORK STRING AND MULESHOE. 09/26/14 - Friday SERVICE RIG AND PERFORM SAFETY COMPLIANCE CHECK. CONT POOH W/ 3-1/2" PH6 AND MULE SHOE. P/U 8.50" BIT & (4) 4-3/4" DCS. TIH W/ 3-1/2" PH6 AND BIT ASSEMBLY BHA, TAG TOP OF CMT @ 2,483' DPM. INSTALL STRIPPER HEAD. P/U AND R/U POWER SWIVEL. EST DRILLING PARAMETERS, ROTATING WT# P/U 40K, SLACK OFF 38K, RPM=70, TORQUE= 2-3K, PUMPING 2 BPM 190 PSI, DRILL DOWN F/2483'- 2493' DPM, WOB= 2-3K. REV/OUT AT 2 BPM UNTIL RETURNS CLEAN. TOTAL PUMPED=25 BBLS. PRESSURE UP ON CMT TO 1500 PSI FOR MIN, "OK". CONT DRILL OUT CMT F/ 2493'- 2680' DPM @ 2 BPM 190 PSI. REV/OUT 1-1/2 TBG VOL EVERY 30'. PRESSURE UP ON CMT TO 1500 PSI @ 3/4 BPM "NO SUCCESS". BROKE DOWN AT 490 PSI, PUMPING IN AT 420 PSI 3/4 BPM. B/O SWIVEL AND WAS FLOWING BACK ON TB SIDE. M/U SWIVEL AND REVERSED UNTIL WELL STATIC. B/O SWIVEL W/ SINGLE AND L/D BOTH. N/D STRIPPING HEAD ADAPTER. POOH W/ 8 1/2" BIT + (4) 4 3/4" DCS- STAND SAME BACK. M/U 3 1/2" PH6 MULE SHOE ON 3 1/2" PH6 WORKSTRING AND TIH TO 2,616'. MIXED 20 BBL POLY PLUG CLEAR GEL PILL- CHECKED INJ RATE AT 1 BPM = 500#s- CIRC PILL DOWN TO EOT (19 BBLS) AND SHUTIN WELL. SQUEEZED PILL IN AT 1 BPM TILL PRESSURE REACHED 900#s THEN CUT RATE BACK TO 3/4 BPM @ 1050#s (PUMPING 23 BBLS 9.9# SW). SHUTIN WELL AT 700#s (540#s AT 1 HR). WAITING ON POLY PLUG TO SETUP. HELD PJSM W/ RIG & HALLIBURTON CREW + CRANE CREW. CHECKED INJ RATE = 1 BPM @ 950#s. R/U HALB IRON AND FILLED LINES- TESTED TO 3000#s. OPENED WELL AND PUMPED 7 BBL SPACER, 20 BBL 15.8# CLASS 'H'CMT- CHASE WITH 5 BBL SPACER + 14.5 BBL 9.9# SW W/ A FINAL INJ PRESSURE OF 960#s/TB- 1050#s/CASING. BUMPED PRESSURE BACK TO 960#S TWICE AT 10 MIN INTERVALS. B/D HALB IRON AND PULLED 7 STANDS. 09/27/14 -Saturday CONT REV/OUT @ 2 BPM UNTIL RETURNS CLEAN. SHUT WELL SICP=300 PSI. CONTINUE WINTERIZING RIG COMPONENTS WHILE WAITING ON CEMENT. BLEED OFF SAME & POOH W/3-1/2" PH6. P/U 3-1/2" TEST ASSY. RIH & RETRIEVE WEAR BUSHING. L/D WEAR BUSHING & P/U TEST PLUG. RIH & SET SAME. R/U BOP TESTING EQUIPMENT & FLUSH/FILL STACK & LINES W/ 8.5# FIW. TEST 11" X 5M BOPS & SURFACE EQUIP AS PER AOGCC & HILCORP SPECS 250 LOW / 2500 HIGH. TESTED FROM MAIN & FUNCTION REMOTE. STATE WITNESS WAIVED BY BOB NOBLE 9/26/14. ALSO CLEANED #1 MUD PIT. L/D 3-1/2" TEST ASSY. P/U WEAR BUSHING. RIH & SET SAME. CLEAR RIG FLOOR & PREP TO TIH. P/U 8.50" BIT & (4) 4-3/4" DC'S. TIH W/ SAME. TO 2590' AND TAGGED CEMENT. CONTINUE WAITING ON CEMENT. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 09/28/14 - Sunday CONTINUE CLEAN CEMENT FROM RIG TANKS & WEIGHT UP 50 BBLS OF FIW TO 9.9#. DRILL OUT CMT F/2590'-2605' DPM, CMT RATTY WOB=IK,TAG HARD CMT.@ 2605'& CONT DRILL OUT SAME TO 2680' DPM, PUMPING 1-1/2 BPM, 80 PSI ,WOB=5K TO 7K,RPM=75,TORQUE=2-3K. REV/OUT UNTIL RETURNS CLEAN EVERY 30'. LOST RETURNS W/REVERSING OUT. MANIFOLD PLUGGED, LOST RETURNS AFTER PUMPING 35 BBLS W/REVERSING OUT. REMOVE VALVE FROM CIRCULATING MANIFOLD AND CLEAN SAME. FLUSH THRU MANIFOLD, CONT REV/OUT @ 2680' DPM UNTIL RETURNS PUMPING @1-1/2 TO 2 BPM 90 PSI. ATTEMPT TO PRESSURE UP ON CSG W/ NO SUCCESS. STARTED TO INJECT IN @ 960 PSI PUMPING 3/4 BPM. PUMPED 3 BBLS TOTAL & SHUT-IN. SICP=960 PSI. BLED TO 623 PSI IN 15 MINS. CONT' TO DRILL OUT CMT F/ 2680'-T/ 2725' DPM. REV/OUT @ 2 BPM 140 PSI WOB= 4K, 75 RPM TORQUE=2K-3K. REV/OUT EVERY CONNECTION UNTIL RETURNS CLEAN. INJECTED INTO FORRMATION AT 450 PSI 1 BPM. REV/OUT 70 BBLS @ 2 BPM 115 PSI UNTIL RETURNS CLEAN & FLUID WAS 9.9# IN/OUT. R/D POWER SWIVEL & L/D SAME. PULL STRIPPING RUBBER & N/D STRIPPING HEAD. POOH W/ 3-1/2" PH6 & DRILLING ASSY. AND TONGS STOPPED BITING PIPE. TROUBLESHOOT & REPAIR MCCOY POWER TONGS. CHANGED DIES & BRAKE BANDS. CONT' TO POOH W/ PH6 & DRILLING ASSY. P/U 3-1/2" MULE SHOE & TIH W/ SAME TO 2616' DPM. R/U CIRC EQUIP. BROKE CIRC DWN TBG & EST INJECTION RATES. 1 BPM=470 PSI, 1.5 BPM=500 PS1,2 BPM=550 PSI. MIX & DISPLACED 20 BBLS POLY PLUG + 4 BBLS OF 9.9# FIW TO E.O.T. CLOSED CIRCULATION & SQUEEZED W/ 27 BBLS OF 9.9# FIW. FINAL INJECTION PRESSURE = 880 PSI. @ 1 BPM, SIDPP=78 PSI. WAIT ON POLY PLUG TO SET UP. CLEAN SLUG TANK, & ACTIVE TANK. 09/29114 - Monday WAIT ON POLY PLUG TO SET UP. FINISHED CLEANING SLUG TANK, &ACTIVE TANK. EST INJ RATES W/RIG PUMP, 1/2 BPM 320 PSI, 3/4 BPM 430 PSI, 1 BPM 520 PSI & 1-1/2 BPM 570 PSI. HELD PRE -JOB SAFETY MTG W/ALL ESSENTIAL PERSONNEL. REVIEW JSA ON PUMPING CEMNT. MIX AND PUMP 7 BBL 8.5# FIW, 40 BBLS 15.8# CLASS "H" CMT & 5 BBLS 8.5# FIW. DISPLACE W/14 BBLS 9.9# FIW. FINAL INJ PRESSURE @ 1 BPM TBG 750 PSI, CSG 920 PSI. WAIT 5 MINS SQUEEZE 1/2 BBL CMT. TBG PRESS=835 PSI, CSG PRESS= 945. WAIT 5 MINS, SQUEEZE 1/2 BBL CEMENT TBG PRESSURE=800 PSI, CSG PRESSURE=900 PSI, WAIT 5 MINS, SQUEEZE 1/2 BBL CEMENT TBG PRESSURE=800 PSI, CSG PRESSURE=900. R/D LINES &POOH TO 2185' DPM, REV/OUT @ 2 BPM 90 PSI UNTIL RETURNS CLEAN. RECOVERD APPROX 2 BBLS CMT. SHUT IN WELL 350 PSI, MONITOR WELL WHILE WAITING ON CEMENT. SICP DOWN TO 140 PSI. R/D CIRC EQUIP. POOH W/ 3-1/2" PH6 & MULE SHOE F/ 2185' DPM. P/U 8.50" BIT & (4) 4-3/4" DC'S TIH W/ 3-1/2" PHIS & DRILLING ASSY. TAG @ 2516' DPM. POOH TO 2504' DPM & N/U STRIPPING HEAD. P/U POWER SWIVEL & R/U SAME. INSTALL STRIPPING RUBBER & PREP TO DRILL OUT CMT. now Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 3�E v r- 09/30/14 - Tuesday CONT DRILL CMT. F/2516'-2550' DPM @ 1-1/26PM 150 PSI REV/OUT EVERY CONNECTION UNTIL RETURNS CLEAN. CEMENT RATTY. POOH TO 2535' DPM & TEST CASING TO 1500 PSI "OK". WAITNG ON CEMENT. EST DRILLING PARAMETERS, PUMPING 3 BPM 230 PSI, ROTARY=70 RPMS, TORQUE=2-3K. CONT DRILL OUT CMT F/2550-2616' DPM. REV/OUT EVERY CONNECTION UNTIL RETURNS CLEAN. TEST CASING TO 1500 PSI "OK". CONT DRILL CMT F/2616-2680' DPM, PUMPING 3 BPM 280 PSI, WOB=2-5K, TORQUE=2-3K. RPM=70. ATTEMPTED TO TEST CASING TO 1500 PSI, WITH NO SUCCESS, PUMPED IN @ 750 PSI AT 1 BPM. R/D & L/D POWER SWIVEL. PULL STRIPPER RUBBER AND N/D STRIPPER HEAD. POOH W/3-1/2" PH6 AND DRILLING ASSY AND RACK SAME BACK IN DERRICK, LOCK OUT EQUIPMENT AND CLEAN OUT RIG TANKS. STARTED IN HOLE WITH MULE SHOE ASSY AND BACKUPS ON MCCOY TONG BACK-UPS. R/D MCCOY TONGS & SET DOWN IN MECHANIC SHOP. DRESS OUT FOSTER TONGS & R/U SAME. TIH W/ 3-1/2" MULE SHOE TO 2647' DPM. MIX 10 BBLS OF SUPER FLUSH & FILL TANKS W/ FRESH WATER. EST INJECTION RATES. 1 BPM=480, 1.5 BPM=650, 2 BPM=750 PSI. HELD JSA ON CMT SQUEEZE PROCEDURE, SQUEEZED 5 BBLS FRESH WATER, 10 BBLS SUPER FLUSH, 5 BBLS FRESH WATER W/ RIG PUMP. MIX & PUMP 50 BBLS PREMIUM "G" CMT, & DISPLACED TBG W/ 9.9# FIW. SHUT-IN W/ 980 PSI. BLED -OFF T/ 903 PSI. BUMPED UP TO 980 THREE TIMES AND PRESSURE DROPPED TO 940 IN 20 MINS. ATTEMPT TO BLEED -OFF, WELL FLOWING ON TBG & CSG. FLOW BACK=8 BBLS ON TBG. P/U 31'& REV/OUT 30 BBLS @ 2 BPM 360 PSI UNTIL RETURNS CLEAN. RECOVERED +/- 12 BBLS OF CMT. SHUT-IN & WELL WAS STATIC. POOH T/2215' DPM. REV/OUT 21 BBLS @ 26PM 80 PSI. SHUT-IN W/ 350 PSI & MONITOR WELL. 10/01/14 -Wednesday' WAITING ON CEMENT. INITIAL SICP= 350 PSI. FINAL SICP= 210 PSI. POOH W/3-1/2" PH6 AND MULE SHOE. M/U 8.50" BIT & (4) 4-3/4" DC'S. TIH W/3-1/2" PH6 AND DRILLING ASSY. SERVICE RIG & PERFORM SAFETY COMPLIANCE CHECKS. CONT' TO TIH W/ 3-1/2" PH6 & DRILLING ASSY. TAG CMT @ 2,620' DPM. N/U STRIPPING HEAD. P/U POWER SWIVEL & R/U SAME. INSTALL STRIPPING RUBBER & MADE CONN. L/U & PUMP 3/4 OF A BBL TO ENSURE PIPE WASN'T PLUGGED. WAIT ON CEMENT. BROKE CIRC IN REV @ 3 BPM 200 PSI. DRILL OUT CEMENT F/ 2,620'- T/ 2,680' DPM. P/U=37K, S/0=37K, ROT=38K, RPM=65, TORQ 2K. DRILLED F/ 2,620'- T/2,648' DPM. W/ 0-1K WOB @ 150 FT/HR. DRILLED F/ 2,648'- T/2,667' DPM WITH 3K TO 4K WOB @ 100 FT/HR. HIT VOID F/ 2,667'-T/2,672' WOB=O @ 500 FT/HR. DRILLED F/ 2,672' -T/2,680 - DPM WOB=5K TO 7K @ 5-10 FT/HR. REV/OUT (1)TBG VOL EVERY CONNECTION @ 3 BPM 200 PSI UNTIL RETURNS CLEANED. ATTEMPT TO PRESSURE UP ON CSG W/ NO SUCCESS. GOT TO 780 PSI @ 3/4 BPM & PRESSURE FELL TO 740 PSI & STARTED TO INJECT INTO WELL. REV/OUT 34 BBLS @ 3 BPM 130 PSI UNTIL CLEAN. PULL STRIPPING RUBBER. R/D POWER SWIVEL & L/D SAME. N/D STRIPPING HEAD & PREP TO POOH. POOH W/3-1/2" PH6 & DRILLING ASSY. CLEAR RIG FLOOR & P/U 3-1/2" MULE SHOE. TIH W/ 3-1/2" PHIS & MULE SHOE TO 2,647' DPM. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 =_W7 77 mom � = 10/02/14 -Thursday, GATHER PERMITS AND PERFORM LOTO ON MUD TANK AND PUMP. SHOVEL SOLIDS FROM UNDER SHAKER AND DISPOSE OF IN CUTTING BOXES. WASH AND CLEAN TANK. POOH W/3-1/2" PH6 AND MULE SHOE WHILE CONTINUNING TO CLEAN OUT SHAKER TANKS. M/U 8.50" BIT AND (4) 4-3/4" DC'S. TIH W/3-1/2" PH6 AND BIT ASSY TO 2,654' DPM. N/U STRIPPER HEAD. P/U AND R/U POWER SWIVEL. MAKE CONNECTION AND INSTALL STRIPPER RUBBER. DRILL OUT CMT F/ 2,680'- T/ 2,730' DPM. P/U=38K, S/0=35K, ROT=39K, RPM=65, TORQUE=2K. DRILLED W/ 3K -5K WOB @ 25-50 FT/HR. REV/OUT (1) TBG VOL EVERY CONNECTION UNTIL CLEAN. PUMPED @ 3 BPM W/ 250 PSI. BROKE THRU @ 2,730' TO 2,735'. REV/OUT 48 BBLS @ 3 BPM W/ 260 PSI UNTIL RETURNS CLEAN. WASH/DRILL OUT HARD CMT STRINGERS F/ 2,735'- T/2,935'. REV/OUT (1) TBG VOL EVERY CONNECTION @ 3 BPM 200 PSI. UNTIL CLEAN. R/D POWER SWIVEL AND WASHED DOWN F/ 2,935'- T/ 3,524' DPM @ 150 FT/HR NO WOB. REV/OUT 50 BBLS. AT 3,524' TAGGED WITH 6K ON BIT. R/U CIRC EQUIP & REV/OUT 90 BBLS @ 2-3 BPM 200-550 PSI. GOT BACK FORMATION SAND, OIL, SCALE, CEMENT, POLY PLUG, & SUPER FLUSH. LOST +/- 16 BBLS DURING CIRCULATION. SHUT DOWN TO SWAP OUT (2) FULL CUTTING BOXES & TRANSFER FLUID TO ACTIVE SYSTEM. CONTINUE WASHING DOWN FROM 3,524' TO 3,541' REVERSING OUT EVERY JT UNTIL RETURNS ARE CLEAN. 10/03/14 -- friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT REV/OUT AT 3 BPM, 310 PSI UNTIL RETURNS CLEAN. FLUID WT. 9.9# IN / 9.9# OUT. RIG DOWN CIRC HOSES. POOH W/3-1/2" PH6 AND BIT ASSY. BREAK DOWN BHA AND LAY OUT BIT. WASH / CLEAN RIG FLOOR AND PREP SAME TO TIH. M/U RETREIVING TOOL AND TIH W/3-1/2" PH6 TO 3,519' DPM. M/U KELLY JT & BREAK CIRCULATION. CONT WASH DOWN F/3,519' TO 3,553' DPM @ 3 BPM 240 PSI. REV/OUT EVERY 12-15 FT DUE TO PIPE TRYING TO PLUG. RECOVERED COAL & SAND OVER SHAKER. UNABLE TO WASH DEEPER. L/D KELLY JT. INSTALL STRIPPER HEAD. P/U & R/U POWER SWIVEL. MAKE CONNECTION & INSTALL STRIPPING RUBBER. CONT ROTATE AND WASH DOWN F/3,553'-3,580' DPM @ 3BPM 250 PSI, RPM=40, WOB=5-6K TORQUE=1-2K. REV/OUT EVERY 10-15' @ 4 BPM, 315 PSI UNTIL RETURNS CLEAN. CONT' TO ROT/WASH DWN F/ 3,580'- 3,590' DPM @ 3 BPM 250 PSI. RPM=30 "0" WOB. REV/OUT 52 BBLS UNTIL CLEAN. TAG TOP OF PLUG & PUMPED DOWN TBG TO FLUSH OFF ANY DEBRIS. S/O & LATCH ONTO PLUG. SET 15K DOWN. UN -SET CIBP. TOOK 10K OVER-PULLTO FREE. BLEW DOWN CIRC LINES W/ AIR. R/D POWER SWIVEL & L/D SAME. N/D STRIPPING HEAD. POOH W/3-1/2" PH6 AND PLUG ASSY SLOW. TIGHT SPOTS @ 2,625'& 2,523' DPM TOOK 3K -5K OVER PULL THRU SAME. L/D PLUG & OVERSHOT ASSY. CLEAR RIG FLOOR & PREP TO TIH. P/U 8.5" TAPERED MILL, BIT SUB, PONY COLLAR, 8.5" STRING MILL, BUMPER & OIL JARS, (4) 4-3/4" DC'S. TIH W/SAME. BHA= 3-1/2 PH 6 BOX X 3-1/2 IF PIN, (4) 4-3/4" DRILL COLLARS, OIL AND BUMPER JARS, 8-/2 OD STRING MILL, 6-1/2" OD PONY COLLAR, BIT SUB AND 8-1/2" TAPERED MILL. TOTAL LENGTH= 175.51'. TIH W/ 3-1/2" PH6 & MILL ASSY. TAG @ 2,505' DPM. L/D (8) JNTS IN V -DOOR & TIH W/ (4) STNDS F/ DRK. P/U POWER SWIVEL & R/U SAME. N/U STRIPPING HEAD & INSTALL STRIPPING RUBBER. MILL/CLEAN OUT CEMENT F/ 2,505'- T/ 2,515' DPM. (WORKED THRU TIGHT SPOT AT 2,508'). Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 a 10/04/14 - Saturday CONTINUE ROTATE AND WASH DOWN F/2,545'-2,733' DPM @ 3 BPM 190 PSI. UNABLE TO WORK DEEPER DUE TO PIPE TORQING UP. RPM=60, WOB=1-2, TORQUE=1-6K. REV/OUT @ 3BPM 190 PSI UNTIL RETURNS CLEAN. RECOVERED METAL CUTTINGS OVER SHAKER. RD AND L/D POWER SWIVEL. N/D STRIPPER HEAD AND PREP RIG FLR TO POOH. POOH W/3-1/2" PHIS AND TANDEM MILL ASSY AND REMOVE PONY COLLAR FROM ASSY. M/U TANDEM 8.50" TAPERED MILL & 8-1/2" STRING MILL TOGETHER & RIH WITH SAME TO 2,723' DPM. UNABLE TO WORK THRU TIGHT SPOT. N/U STRIPPING HEAD. P/U POWER SWIVEL & R/U SAME. INSTALL STRIPPING RUBBER. ATTEMPT TO ROT THRU TIGHT SPOT @ 2,732' DPM W/ NO SUCCESS. TORQUE UP TO 6K @ SET 5K DOWN & TOOK 10K TO PULL FREE. REV/OUT 35 BBLS @ 3 BPM 180 PSI UNTIL RETURNS CLEAN. METAL BACK IN RETURNS (— 1/2 LB). BLEW DWN CIRC LINES W/ AIR. R/D POWER SWIVEL & L/D SAME. N/D STRIPPING HEAD. POOH W/3-1/2" PH6 AND TANDEM MILL ASSY. L/D TAPPERED MILL & BIT SUB. P/U 8.5" IMPRESSION BLOCK. TIH W/ 3-1/2" PH6 & IMPRESSION BLOCK ASSY & TAGGED @ 2,732' DPM. SET 10K DOWN & TOOK 5K OVER PULLTO FREE. POOH W/ 3-1/2" PH6 & IMPRESSION BLOCK ASSY. B/O AND INSPECTED IMPRESSION BLOCK. FOUND EDGES ON TOP ROLLED UP AND BOTTOM ROLLED DOWN. BLOCK SLIGHTLY EGG SHAPED WITH AN 8.50" X 8.47 OD. P/U & M/U 8-1/2" TANDEM MILL ASY. RIH TO 1,100'. 10/05/14-Sunday CONT. TIH W/3-1/2" PH6 AND TANDEM MILL ASSY TO 2,720' DPM. INSTALL STRIPPER AND N/U SAME. P/U & R/U POWER SWIVEL. MAKE CONNECTION. INSTALL STRIPPER RUBBER & EST DRILLING PARAMETERS. PUMPING @ 3 BPM 190 PSI, RPM=40 WOB=2-7K. ROTATE AND WASH DOWN. TAG @ 2,732' DPM. MILL ON CASING FROM 2,732'-2,739' DPM. UNABLE TO WORK DEEPER. REV/OUT @ 3-1/2 BPM 230 PSI UNTIL RETURNS CLEAN. 9.9# IN / 9.9# OUT. L/D SINGLE. R/D & L/D POWER SWIVEL. PULL STRIPPER RUBBER AND N/D STRIPPER HEAD. PREP R/FLR TO POOH. POOH W/3-1/2" PH6 AND TANDEM MILL ASSY. AND B/O SAME. FOUND ALL CUT-RITE GONE ON LEADING EDGE OF STRING MILL AND THE SAME WORN DOWN TO 7-5/8" OD. P/U WEAR BUSHING R/R TOOL & PULL WEAR BUSHING. P/U 3-1/2" TEST JNT & TEST PLUG. RIH & SET SAME. M/U 3-1/2" TEST ASSY. R/U BOP TESTING EQUIP. FLUSH THRU & FILL BOP'S & ALL SURFACE LINES/EQUIP W/ 8.5# FIW. REPLACE LEAKING TEST HOSE & TEST SAME. TEST 11" X 5M BOPS & SURFACE EQUIP AS PER AOGCC & HILCORP SPECS 250 LOW / 2500 HIGH ON CHART. TESTED FROM REMOTE. FUNCTION TESTED MAIN & PERFORMED KOOMEY TEST. STATE WITNESS WAIVED BY JIM REGG ON 10/05/14 @ 08:30 HRS. PULL TEST PLUG. B/D & L/D TEST ASSY. P/U & SET WEAR BUSHING. R/D TESTING EQUIPMENT. P/U 6" TAPERED MILL, 6.5" PONY COLLAR, 8.125" STRING MILL, BUMPER & OIL JARS, (4) 4-3/4" DC'S --TOTAL LENGTH= 177.14'. RIH 3-1/2" PH6 & 8-1/8" STRING MILL ASSY. TO 2,732' AND TAGGED WITHY 3K DOWN WORKED MILL THRU WITH 9K DOWN. CONTINUED IN HOLE TO 3,200' AND WORKED MILL THRU TIGHT SPOT WITH 3K DOWN. CONTINUE IN HOLE TO 4,003'. REVERSE CIRCULATE AND CONDITION FLUID. 14/06/14 - Monday Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 1 6/28/14 10/11/14 it CONT REV/OUT @ 3-1/2 BPM 340 PSI UNTIL RETURNS CLEAN. 9.9# IN / 9.9# OUT. POOH W/3-1/2" PH6 AND 6" MILL ASSY. B/D MILL ASSY BHA. M/U 8.50" TAPERED MILL & (4) 4-3/4" DC'S. TIH W/3-1/2" PH6 & MILL ASSY TO 2,745' DPM. NO INDICATION OF TIGHT SPOT. WORK MILL FROM 2,745' UP TO 2,730' SEVERAL TIMES. CONT TIH W/MILL ASSY. TAG @ 9,477' DPM. SPACE OUT AND R/U KELLY JT. SERVICE RIG. R/U CIRC EQUIP. REV/OUT 75 BBLS @ 3 BPM 325 PSI UNTIL RETURNS CLEAN. WASH DOWN F/ 9,477'- 9,507' DPM @ 10-50 FT/HR. WOB= 3K WHILE REV/OUT @ 3 BPM 390 PSI. GETTING CEMENT, COAL, & FORMATION SANDS BACK & SOME GAS AT 9,507'. SET 6K DOWN & UNABLE TO WASH OUT. REV/OUT 95 BBLS @ 3 BPM 380 PSI UNTIL CLEAN. W/ 8 BBLS LOST. SHUT DOWN PUMP & AND WELL U TUBING. L/U & CIRC 180 BBLS DOWN TBG. NO GAIN/NO LOSS. BUILD & PUMP A 6 BBL 11.2# NaBr SLUG & CHASED W/ 3 BBLS OF 9.9# FIW. MONITORED FOR 5 MIN AND WELL STATIC. POOH W/3-1/2" PH6 AND 8.50" TAPPERED MILL ASSY. B/O & L/O SAME. CLEAN RIG AND SERVICE RIG. 10/07/14 - Tuesday M/U ENVENTURE EXPANDABLE CASING PATCH LAUNCHER. TIH W/3-1/2" PH6 LAUNCHER ASSY, TAG AT 2,728' DPM. MAKE SEVERAL ATTEMPTS TO WORK LAUNCHER AND CSG THRU TIGHT SPOT. NO SUCCESS. SETTING 15K DOWN WITH 12K OVERPULL. POOH WITH 3-1/2" PH6 AND CSG LAUCHER ASSY. B/D CASING PATCH LAUCHER ASSY AS PER ENVENTURE REP AND LAY DOWN SAME. RECHARGE, PRECHARGE IN ACCUMULATOR BOTTLES TO (1000 -1100 PSI) AS PER REGULATIONS. WASH/CLEAN RIG AND PLATFORM WHILE WAITING ON EQUIPMENT TO ARRIVE FROM DOCK TO COMPLETE WELL D-31RD. WASH/CLEAN RIG AND PLATFORM. WENT THRU MUD PUMP. C/O MIXING PUMP. CLEANED DRAINS, SERVICED EQUIP. R/D FOSTER TONGS, DRESSED MCCOY TONGS FOR 3-1/2" TBG & R/U SAME. OFF-LOAD 3-1/2" PROD TBG, COMPLETION PACKER, GLM & SAFETY VALVE F/ BOAT. LAYOUT & TALLY SAME. SLIP & CUT 65' OF DRILL LINE. CALIBRATE DRAWWORKS & HMI. SET C.O.M. & TEST SAME. CONT' WITH GENERAL HOUSEKEEPING AROUND RIG/PLATFORM WHILE WITING ON CROSSOVER TO ARRIVE FROM MACHINE SHOP. —777 10/08/14.,- Wednesday;' WINTERIZING AND DOING RIG REPAIRS WHILE STANDING BY FOR COMPLETION STRING X -OVERS TO ARRIVE LOCATION. 10/09/14 -Thursday Waiting on x/overs to be machined for completion string. Pull wear bushing. M/u WLRG, 2 pups, x -nipple w/ RHC plug installed, 2 pups, x/o 9/5/8 40# HS packer, x/o, pups, x/o 1 jt super max tbg, x/o GLM, x/o. RIH with 3.5, 9.2#, L-80 supermax tbg at 30 ft per minute per jt. drifting each jt. Make up SCSSV and control line function valve, test line to 2500 psi for 15 minutes. Continue running in hole w/ 3.5 supermax tbg running control line to 2,433 ft. Make up hanger. Waiting on x/o for landing jt. 10/10/14 - Friday Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-31RD 50-733-20215-01 176-074 6/28/14 10/11/14 _ F� PU 3.5 landing jt. MU same to hanger. Installed control line to hanger while waiting on xover for completion string. Land hanger and run in hold down pins. Laydown 3.5 landing jt and PU 4.5 landing jt and MU in hanger for wire line work. Rig up slickline. Test lubricator to 3300 PSI (OK). RIH with 2.80 gauge ring tag at 2,499' WLM. POOH with same. Rig up slickline. PT LUB TO 3300 PSI, Good. RIH W/ 2.80" G. RING TO 2,499' KB - TAG POOH. Drop pkr bar (wlm showing depth not correct check pipe figures and found that we were 2 jts off depth) DROP BALL AND ROD. STAND BY FOR PACKER TEST. DECIDE TO PULL 2 JOINTS OUT OF PRODUCTION STRING. RIH with 2" JDC latch pkr bar @ 2,494' WLM. POOH (failed to retrieve bar). RIH with same and latch bar @ 2,494' WLM. POOH, retrieved bar, rig down slickline and backout lock down pins. RIH W/ 2" JDC TO 2,494' KB, LATCH AND PULL BALL AND ROD, POOH. LAY DOWN LUB. STAND BY FOR DRILLING TO PULL 2 JOINTS. POOH with hanger and 2 jts of tbg and lay down same. Make up hanger and landing jt. Land hanger and run in lockdown pins. Drop pkr bar and rig up to set pkr @ 2,411'. Pressure up on tbg pkr set @ 2100 PSI cont pressure up to 2800 PSI and hold for 15 min. Bleed off pressure and start to rig up on csg to test same. Rig up on csg value to test pkr @ 2500 PSI on chart for 30 min. Test held on chart for 30 min. Rigging up wireline to test lubricator to 2500 PSI. Test held on lubricator to 2500 PSI. RIH with retrieve tool to get bar at 2,429' run 2" JDC. RIG UP SLICKLINE. PT LUB TO 2500 PSI. GOOD. RIH W/ 2" JDC TO 2,429'KB, LATCH AND PULL BALL AND ROD. POOH. Retrieve bar to top of lubricator then RIH to retrieve plug body at 2,433' tool was 3" GR. RIH W/ 3" GR TO 2,433'KB, LATCH AND PULL RHC PLUG BODY. POOH. OOH W/ PLUG BODY. RIG DOWN SLICKLINE. Rig down lubricator and move equipment. Set BPU, rig down landing joint. Rig down rig floor. BOPS and riser. Break every other bolt on riser at wellhead. Rig down high pressure hose from casing valve and high pressure hose to water plug. Start rigging down BOPS. Lay out riser. 10/11/14-Saturday Nipple up tree and wing valve. Pull BPV and install 2 way check. Test tree on chart 3500 psi 25 min, pull 2 way check. Test void 5000 psi for 20 min ok. Start preparing rig to skid from D-31RD. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 07, 2014 2:04 PM To: 'Dan Marlowe' Cc: Juanita Lovett; Daniel Taylor; Ted Kramer Subject: RE: D-31rd Sundry 314-367, PTD 176-074 Dan, Approval granted to modify the sundry 314-367 to complete well as proposed in the attached drawing. Completion must have packer and ScSSV as you show in your proposed well sketch. nn / P -,4 '— Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office A/-•7• or 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 Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Tuesday, October 07, 2014 1:53 PM _ To: Schwartz, Guy L (DOA) SCWVD Cc: Juanita Lovett; Daniel Taylor; Ted Kramer Subject: RE: D-31rd Sundry 314-367, PTD 176-074 Guy As discussed we haven't had success correcting the casing issues at 2,718'. At this time I would like to run the following completion that will allow us to SZ sands and see if they were charged with leaking Gas Lift gas or if there is something more there. See attached drawing of the proposed completion. Thanks Dan From: Dan Marlowe Sent: September 23, 2014 9:33 AM To: 'Schwartz, Guy L (DOA)' Cc: Juanita Lovett; Daniel Taylor; Ted Kramer Subject: RE: D-31rd Sundry 314-367, PTD 176-074 Good morning sir We have evaluated our caliper data and followed up with pressure / injectivity tests with an RTTS tool. Our casing tests to 2500 psi above 2,650' and below 2,730' Looks lokp h.ol s at 2,665' and 2,720' with 2,720' being the worse of the two. Injection rates are as o ows 1 bpm @ 190 psi 2 bpm @ 350 psi 3 bpm @ 440 psi We are running in with a mule shoe now and are going to run in with a forward with the plan to squeeze cement this morning. From: Schwartz, Guy L (DOA)[mailto:guy.schwartz(a)alaska.gov] Sent: September 17, 2014 3:34 PM To: Dan Marlowe Cc: Juanita Lovett; Daniel Taylor; Ted Kramer Subject: RE: D-31rd Sundry 314-367, PTD 176-074 Dan, Your plan below is approved. Send me sqz plan as you mention below. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Dan Marlowe[-iailto:dmarlowe('Ohilcorp.corn] Sent: Wednesday, September 17, 2014 3:31 PM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett; Daniel Taylor; Ted Kramer Subject: D-31rd Sundry 314-367, PTD 176-074 Guy As discussed, I had to modify plans slightly due to the casing leak in D-31rd. We tried to weight up and kill the well but the G -zone kept stealing my brine and the pressure would come back to haunt us. Progress so far • Cleaned out tubing • CIBP set at 9,950' between bottom GLM and packer • Killed well with 9.9 ppg brine • Nippled down tree and nippled up BOP • Cut and recovered pipe to 3,040' • Conducted a free point and determined tubing free all the way to bottom (had suspected sand on backside) Plan for the next several days • Cut production tubing at 9,815' and recover. • Run a taper mill / watermelon combo to —9,800' cleaning the iron sulfide deposits out of the casing • Run a casing caliper to —9,800' determining extent of suspected casing damage • Run and set a retrievable bridge plug w/ sand cap to just below casing damage • Decision point on Squeeze off of casing leak w/ 20-30 bbls Cement (most likely) or Poly Plug Clear Gel (least likely) based on size of leak • Send an Email documenting squeeze plan to Guy Schwartz, Text Guy a heads up if it falls during the weekend (verbal approval already received, just need to document final plan) • Conduct squeeze • Clean out to top of retrievable bridge plug • Pressure test casing to 2500 psi and chart for 30 minutes • recover retrievable bridge plug • Resume operations per Sundry procedure at step 9 Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(D-hilcorp.com HilcoM A Company Built on Energy 1w 29',d 13-3/8" Casing Dannage 2,480'-3,420' Stage Collar 7,orr RKB = 40.5' 1 2 3 4 �t �t c. vb G u TD =10,630" PBTD =10,593' Max An64e=38.6* @ 4,917 PROPOSED McArthur River Field, TBU Well: D-31RD Completed: FUTURE CASING AND TUBING DETAIL SIZE W"T GRADE CONN ID TOP BTM. 20" 94 H-40 - 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing 9,930' 3.00 5.968 McMurry Maceo, 3-112' SMO -2 GLM, 1-1/2', RK w/ OGLV installed 11/25108. 10,418' 9,950' 8,921' 9.2# CIBP nperma) .992 Surf ±2,50(' HES, No -Go Seal Assembly, 10', Molded 9 10,009' 4.00 8.120 HES, 9-5/8", 36#-59.4#, 'BWD' Permanent Packer 10 3-1/2" 9.2# L-80 Butt SC 2.992 9,601' 10,012' JEWELRY DETAIL NO. Depth ID OD Item Fish: 40.50' - - Tubing Hanger Drillex Motor, 2.625" Wash Pipe and Shoe ±315 32' of 2-5/8" Perf Gun top at 10,502' Top (MD) SSSV 2 ±2,410' Amt Condition Production racker 3 ±2,440' 2 813 8,770' X -Nipple 35' ±2,450' 03/31/1998 G-3 WLEG 10,338' 8,829' 8,853' 28' Open 03/31/1998 9,601' 10,358' 10,418' -, I tubing E -Line cut 6 9,930' 3.00 5.968 McMurry Maceo, 3-112' SMO -2 GLM, 1-1/2', RK w/ OGLV installed 11/25108. 10,418' 9,950' 8,921' 8,928' CIBP 8 10,012' 3.06 4.500 HES, No -Go Seal Assembly, 10', Molded 9 10,009' 4.00 8.120 HES, 9-5/8", 36#-59.4#, 'BWD' Permanent Packer 10 10,013' 4.00 5.020 HES, Seal Bore Extension, 8' Long 11 10,021' 2.992 5.720 HES, Tubing Adapter 12 10,032' 2.813 3.970 HES, 'X' Nipple, 2.813 13 10,041 2.992" 6.030 WLEG Fish: 10/22/1993 2.74" O.D. Overshot & Rope Socket,15"Long Disconnect, XO, 2-3/8" Drillex Motor, 2.625" Wash Pipe and Shoe 09/28/1986 32' of 2-5/8" Perf Gun top at 10,502' Updated By: DEM 10/07/14 Perforation History Zone Top (MD) Btm (MD) (TVD) (TVD) Amt Condition Date G-2 10,240' 10,275' 8,770' 8,799' 35' Open 03/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Open 03/31/1998 G-4 10,358' 10,418' 8,870' 8,921' 60' Open 03/31/1998 G-4 10,418' 10,426' 8,921' 8,928' & Open 10/01/1990 Updated By: DEM 10/07/14 ' OF 9 VI LQ — C. -A-1 Lk THE STATE C"D".i e of JIL GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Oil Pool, TBU D-31 RD Sundry Number: 314-367 Dear Mr. Marlowe: 333 Wesi Seventh Avenue Anchorage, Alaska 99501-3572 Mcin: 907.279.1433 �;,x: 907.'176.71542 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, 9ahy P. 4�"oerster Chair DATED this fflay of June, 2014. Encl. SCANNED OCT, j J 2014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUN 16 2014 AOGCC� 14, 1. Type of Request: Abandor ❑ Plug for RedrR ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspenc ❑ Plug Perforations ❑ Perforate 0. Pull Tubing Fa] Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install Casing Liner/ Run ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 176-074 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20215-01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A' Will planned perforations require a spacing exception? Yes ❑ No Q Trading Bay Unit/ D-31 RD , 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018729 McArthur River Field / Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective DepthEffective Depth TVD (ft): Plugs (measured): Junk (measured): 10,630 9,103 10,593 9,071 None 10,502'& 10,491' Casing Length Size MD TVD Burst Collapse Structural Conductor 718' 20" 718' 718' 1,530 psi 520 psi Surface 2,492' 13-3/8" 2,492' 2,387' 3,090 psi 1,540 psi Intermediate Production 10,630' 9-5/8" 10,630' 9,103' 5,750 psi 3,090 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,240'- 10,426' 8,770'- 8,928' 3-1/2" 9.2# / N-80 10,012 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BWD Packer / HES "XXO" SSSV 10,009' (MD) 8,575' (TVD) / 344' (MD) 344' (TVD) 12. Attachments: Description Summary of Proposal E 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch [A Exploratory ❑ Stratigraphic ❑ Development Q - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/15/2014 Oil Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(oWIcorp.com Printed Name Dan Warlowe Title Operations Engineer 1/Signatu _ - - lid Phgne (907) 283-1329 Date 6/16/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3��--L- 3 Plug Integrity ❑ BOP Test [0 Mechanical Integrity Test ❑ Location Clearance ❑ Other. ZSdL L�j� bof r-- ❑ Subsequent Spacing Exception Required? Yes No Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 17 11 //'�� D �r /y Submit Form and Form 10-403 (Revised 10/2012) Approval pRa1cG ja j4A Lnths from the date of approval. Attachments in Duplicate �/ 11 �` VVV 1 ��` I = Jug 19 Zoe Hilcorp Alaska, LLC. Well Work Prognosis Well: D-31rd Date: 06/12/14 Well Name: Trading Bay Unit D-31rd API Number: 50-733-20215-01 Current Status: Shut-in Producer (Gas Lift) Leg: Leg #A-1 (NE corner) Estimated Start Date: July 15, 2014 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 176-074 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current Bottom Hole Pressure: — 2,800 psi @ 8,800' TVD 0.32 psi/ft based on 2009 pressure data Maximum Expected BHP: — 2,800 psi @ 8,800' TVD 0.32 psi/ft based on 2009 pressure data Max. Allowable Surface Pressure: 0 psi Using 0.46 psi/ft SW gradient to surface Brief Well Summary D-31RD is a gas -lift completion that has cork screwed tubing and a casing leak contributing sand and gas. This workover will remove the existing completion and clean out the well. The casing will be inspected with a caliper and a casing bond log and repaired with a liner tied back to above the damage or to surface. Procedure: 1. At least one day prior to rig move, stop lift gas to well and bleed down tubing and casing. 2. Skid rig and RU HAK Rig 1 over D-31rd well slot. 3. Punch tubing above packer or pull lowest gas lift valve possible. 4. Circulate FIW to displace hydrocarbon from well. 5. Circulate kill weight fluid to kill well. 6. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. y 7. RU E -line and cut tubing as deep as possible ideally in the middle of the first full joint of tubing just above the packer at 10,009'. (Suspect corkscrewed tubing at 9,600') 8. RD E -line. POOH laying down tubing and GLMs. 9. PU overshot and jars on workstring, jar and release seals from anchor and POOH with seal assembly. 10. Mill and retrieve production packer at 10,009'. 11. Cleanout fill and fish to—10,500'.- 12. PU Bit and scraper and RIH to "'10,200', Circulate well with KWF to clean wellbore. POOH. t13. RU E -line and run casing caliper and cement bond log to —10,200'. 14. PU retrievable test packer and RIH to top of casing damage found in caliper survey. Set packer, test backside to 2,500 psi to confirm casing integrity. Hold for 30 minutes, record with a chart re�co der. d� POOH. s 15. PU and run 7-5/8" liner to above casing damageo r "'"�" 0 1�7 tZ��� 6 PU and RIH with RTTS / Storm Acker het same at 200' and han off strin Pressure test to 1500 si V b g• p • 415(t Release Release from storm packer, POOH. Install new casing spool_ Retest all BOP breaks to 2,500 psi and f �.. . chart. 5�� 117. RU Cementing Company and cement 7-5/8" casing in place according to cementing procedure. WOC. I d�r 18. RU 7-5/8" cleanout assembly and clean out casing to 10,500. Circulate hole clean. POOH Hilrnrp Alaska. LLC Well Work Prognosis Well: D-31rd Date: 06/12/14 19. RU E -line. RIH with Gamma Ray and CCL to 10,500'. Log out of hole running Gamma Ray and CCL. RD E -line. 20. Pressure the 7-5/8" casing on a chart recorder to 2,500 psi for 30 minutes. 21. PU TCP guns and RIH and re -perforate the G -zone zone per the Perf Recommendation. 22. PU, RIH with ESP completion. 23. ND BOP, NU wellhead and test. 24. Turn well over to production. 25. Conduct a no -flow test within 2 weeks after stabilized flow and water cut is achieved. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. New Wellhead Diagram SCHEMATIC MgArthur River Field, TBU Well: D-31rd u;"wnmA.. LLC Completed: 11/27/1997 F1 RKB = 40.5' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 H-40 JEWELRY DETAIL OD Item 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' Tubing 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK G4 7,200' 3.00 3-1/2" 9.2 L-80 BT &CSC 3.00 5.968 10,012' NO. Depth ID JEWELRY DETAIL OD Item 1 40.50' - - CIW, 11" x 4", 5M, DCB S gle Tubing Hanger 2 41.75' 2.992 4.500 Crossover, 4-1/2" Buttress A 3-1/2" Buttress 3 344' 2.813 4.330 HES, `XXO' SSSV (2.813 .D.), HES SSSV Installed 4 2,510' 3.00 5.968 McMurry Macco, 3-1/2" S O-2 GLM , 1-1/2", RK 10,310' 4,414' 3.00 5.968 McMurry Macco, 3-1/2" S O-2 GLM, 1-1/2", RK Open 5,809' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 8,870' 6,647' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK G4 7,200' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 8' 7,753' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 8,305' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 8,856' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 9,376' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK 9,930' 3.00 5.968 McMurry Macco, 3-1/2" SMO -2 GLM, 1-1/2", RK w/ OGLV installed 11/25/08. 5 10,012' 3.06 4.500 HES, No -Go Seal Assembly, 10', Molded 6 10,009' 4.00 8.120 HES, 9-5/8", 36#-59,4#, `BWD' Permanent Packer 7 10,013' 4.00 5.020 HES, Seal Bore Extension, 8' Long 8 10,021' 2.992 5.720 HES, Tubing Adapter 9 10,032' 2.813 3.970 HES, `X' Nipple, 2.813 10 10,041' 2.992 6.030 Wire Line Re-entry Guide Fish: 10/22/1993 2.74" O.D. Overshot & Rope Socket, I 5"Loni Disconnect, XO, 2-3/8" Drillex Motor, 2.625" Wash Pipe and Shoe 09/28/1986 32' of 2-5/8" Perf Gun top at 10,502' Zone FILL Btm (MD) 11/14/2008 1 2.75" GR to 10075'. 2" DD bailer to 10423' - sand. PBTD = 10,593' TD = 10,630' MAX HOLE ANGLE = 38.6° @ 4,917' DRAWN BY: TCB Updated by:DEM 2014-05-01 Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Condition Date G-2 10,240' 10,275' 8,770' 8,799' 35' Open 03/31/1998 G-3 10,310' 10,338' 8,829' 8,853' 28' Open 0313111998 G4 10,358' 10,418' 8,870' 8,921' 60' Open 03/3111998 G4 10,418' 1 10,426' 8,921' 8,928' 8' Open 10/01/1990 PBTD = 10,593' TD = 10,630' MAX HOLE ANGLE = 38.6° @ 4,917' DRAWN BY: TCB Updated by:DEM 2014-05-01 PROPOSED tlilrurp .\la.ka. LL1: RKB = 40.5' 20",d 13-3/8" Stage Collar @ 7 077' 9-5/8" TD =10,630" PBTD =10,593' Max Angle --38.6° @ 4,917' SIZE WT McArthur River Field, TBU Well: D-31RD Completed: 11/27/1997 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" 94 H-40 2.74" O.D. Overshot & Rope Socket,15"Long Disconnect, XO, 2-3/8" 19.124 Surface 718' 13-3/8" 61 K-55 Seal Lock 12.51 Surface 2,492' 9-5/8" 40 N-80 BTC 8.835 Surface 2,783' 9-5/8" 47 N-80 BTC 8.681 2,783' 8,366' 9-5/8" 47 P-110 BTC 8.681 8,366' 10,630' 1-5/8" c. L-80 VAM SLIJ-II 6.875 Surf ±10,500' Tubing ±8,850' 22 Futurf G-4 10,358' 2-7/8" 6.5 L-80 8rd EUE 1 1.441" Surf ±10,050' JEWELRY DETAIL NO. Depth ID OD Item 1 40.50' Tubing Hanger 2 Btm of ESP Fish: 10/22/1993 2.74" O.D. Overshot & Rope Socket,15"Long Disconnect, XO, 2-3/8" Drillex Motor, 2.625" Wash Pipe and Shoe 09/28/1986 32' of 2-5/8" Perf Gun top at 10,502' Updated By: JLL 06/12/14 Perforation History Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Condition Date G-2 10,240' 10,275' 8,770' 8,799' 35' Open 03/31/1998 G-2 ±10,246' ±10,269' ±8,775' ±8,794 23 Future G-3 10,310' 10,338' 8,829' 8,853' 28' Open 03/31/1998 G-3 ±10,312' ±10,334' ±8,831' ±8,850' 22 Futurf G-4 10,358' 10,418' 8,870' 8,921' 60' Open 03/31/1998 4 ±10,362' ±10,393' ±8,874' ±8,900' 31' G-4 ±10,401' ±10,417' ±8,907' ±8,920' 16 G-4 10,418' 10,426' 8,921' 8,928' 8' Open 10/01/1990 Updated By: JLL 06/12/14 Hilmirp AlInAm, LII: Dolly Varden D-31 R D 13 3/8 X 9 5/8 X 3 1/2 Tree, Block, CIW-F, 11 5M X 41/16 5M run X 3 1/8 5M wing, double master and wing valve, EE trim prepped for 7" FBB type hanger neck, w/ % control line exit Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Dolly Varden Platform D-31RD Current 05/03/2014 Tubing hanger, CIW-DCB- FBB, 11 X 4 Y: EUE 8rd lift X 4 % I BT susp, w/ 4" type H BPV, 1/8 non continuous control line, 7" extended neck prep BHTA, CIW, w/ internal knockup cap, 4 1/16 5M FE 1/16 5M FE, 1 trim 2 1/16 5M FE, AA trim Hill"irp Alitoka. ➢.I A, Dolly Varden D-31RD 133/8X95/8X31/2 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 21/16 5M EFO BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union Dolly Varden Platform D-31RD Proposed 05/03/2014 Tubing hanger, CIW-DCB-ESP, 11 X 3 % EUE lift and susp, w/ 3" type H BPV profile, 5 X EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, WKM-M, 3 1/8 5M FE, w/ MA -16 operator Adapter, CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE, prepped for 5'/4 ESP neck, 2-'/ npt continuous control line ports Valve, WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Hilmrp Ala.ka. MA Dolly Varden Platform 2014 Workovers BOP Drawing (HAK #1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 Ili6rorp Alaska. H.0 Attachment #1 Hilcorp HAK #1 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) Hileorp Alaska, LLC Hilcorp HAK #1 BOP Test Procedure Attachment #1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. Hileorp Alaska, LLC Hilcorp HAK #1 BOP Test Procedure Attachment #1 ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-3. This is the HCR (the hydraulic controlled remote) valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual' so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Hilcorp HAK #1 BOP Test Procedure Hilrorp Alaska. f,l.c Attachment #1 Diagram A: Dolly Varden BOP stack and Riser Arrangement — Typical for Single Completion Dolly Varden Platform 2014 BOP Stack UTAK #0 01/10/2014 Dolly Varden Platform 2014 Workovers BOP Drawing)HAK #1) Quail Tool Rental Stack Hileorp Alaska, LLC. Diagram B: Dolly Varden Choke Manifold Hilcorp HAK #1 BOP Test Procedure Attachment #1 From Bop Choke Line 2 1/16 5M Unibolt Flange HihorpHAK#1 BOP Test Procedure Attachment #1 v- Hi|corpHAK#1 BOP Test Procedure Attachment #1 solo 41 Ui CL Erl U- z C) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM' John Crisp,~°' ~ ~. SUBJECT: Petroleum In~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON-CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep' Mark Murietta AOGCC Rep' John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Data ' Pilots SV SSV Well Type Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorCVCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1~60360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 ll0i 80 70 P P 43 OIL D-32 1700370 110 80 75! P P P OIL D-40RD 1820830 110 80 80! P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70: P P 9 OIL '~48 1921540 110 80 801 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 9o r)av Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jcl Unocal Energy Resour¢ ivision Unocal Corporation .-.¢- 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) October 5, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: Dolly Varden Platform Well D-31RD APl Number 50-733-20215 On May 24, 1995 the following intervals were perforated in Well D-31 RD: BENCH TOP (MD) BOTTOM (MD) FEET G2 10,246 10,272 26 G3 10,315 10,335 20 G4 10,348 10,356 8 G4 10,361 10,415 54 Total 108 Attachment Very truly yours, ,,~ ~- i ~ ~ ,,,~' ?: ~7,~ ~ ~.. .......... Candace Williams STATE OF ALASKA ALASK~--,.~.~IL AND GAS CONSERVATION CO~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate m Plugging m Perforate X Pull tubing __ Alter casing__ Repair well __ Pull tubing Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development X Exploratory 106' KB above MSL feet -- 3. Address Stratigraphic __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Service__ Trading Bay Unit 4. Location of well at surface Leg A-1 Cond. #11 DollyVarden Platform 8. Well number 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM D-31 RD At top of productive interval 9. Permit number/approval number 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM 76-74/93-233 At effective depth ~'~. ~'" ; ~ ~. 10. APl number 1,154' FEL, 406'FNL, Sec. 6-8N-13W-SM ! ~ ~ - - 50-733-20215 At total depth '~-- ~ ' ...... 11. Field/Pool 1,150' FEL, 395' FNL, Sec. 6-SN-13W-SM G-Zone 12. Present well condition summary Total depth: measured 10,630' feet Plugs (measured) None true vertical 9,101' feet Effective depth: measured 10,593' feet Junk (measured) 10,502' 32' 2-5/8" Perf Gun true vertical 9,071' feet 10,491' 25' Coil Tubing Fish Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,492' 13-3/8" 2,492' 2,386' Intermediate Production 10,630' 9 -5/8" 2,200 sx 10,630' 9,101' Liner Perforation depth: measured G-2 10,246'- 10,272' MD 8,745'-8,797' TVD G-3 10,315'-10,335' MD 8,833'-8,851' TVD G-4 10,348'- 10,356' MD 8,854'-8,861' TVD true vertical G-4 10,361'-10,415' MD 8,865'-8,911' TVD G-4 10,364'- 10,424' MD 8,877'-8,928' TVD Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson MOdel Rh-1 Packer @ 10,042', Camco TRBV @ 322'.-. 13. Stimulation or cement squeeze summary ~-~ . 1~1 v [~ bj Intervals treated (measured) 0CT 'i '~ Treatment description including volumes used and final pressure ~$[~3~ Uit & Gas Cons. C0mmiss[0_n 14. Representative Daily Average Production or Injecti~)~- I~-~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5/8/95 658 259 65 1131 150 Subsequent to operation 6/15/95 607 632 37 1141 125 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations -- Oil X__ Gas Suspended __ Service 17. I hereby ce~rtify that the f. oregoing is.tr~ke and correct to the best of my knowledge. Signed r~i--~~ Title Drilling Manager Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALASKA ALAST~-~ OIL AND GAS CONSERVATION COMIv,.,~SION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown Stimulate Plugging Perforate X Pull Tubing Alter Casing Repair Well Other · Operations Performed: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory -- S t ratig rap h ic -- Service -- 4. Location of well at surface Leg A-1 Cond. #11 Dolly Varden Platform 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-SN-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-31RD 9. Permit number/approval number 76-74 / 93-233 10. APl number 50- 733-2021 11. Field/Pool G-Zone 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10,630' feet Plugs (measured) 9,101' feet 10,593' feet Junk (measured) 9,071' feet Length Size Cemented 2,492' 13-3/8" 10,630' 9-5/8" 2,200 sx measured G-2 10,246' - 10,272' G-3 10,315' - 10,335' true vertical G-4 10,364' - 10,424' None 10,502' 32' 2-5/8" Perf Gun 10,491' 25' Coil Tubing Fish Measured depth True vertical depth 2,492' 2,386' 10,630' 9,101' MD 8,745'- 8,797' TVD MD 8,833'- 8,851' TVD MD 8,877' 8,928' TVD Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model Rh-1 Packer @10,042', Camco TRBV @ 322' RECEIVE[ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure DEC 1:~' i!;"~3 Aisska Oil & Gas i.,..s u.mmtssio,- '. ~,nchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior towell operation 630~ 255 36 900 Subsequent to operation 1,084 ~ 410 45 820 120 110 ! 5. Attachments 116. Status of well classification as: I Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas__ 7. I here~rtJfYsigned '~-~th~3t the foreg.oin~o_ the best of my knowledgeTitle~ ~[,t~,l~,/k,,~ (~ Form 10-404 Rev 06/15/88 Suspended Service Date tS, E,:,q,,, fi SUBMIT IN DUPLICATE--~ ~ DAILY WELL OPERATIONS D-31RD 9/6-7/93 RU E-line. PI ]ub to 2500 psi. Good. RIH w/ 30' 2-1/8". 4 SPF, 45° phasing perf gun. Flowed well to obtain underbalance and perforated the following: RUN BENCH DEPTH (DIL) RESULT I G-4 10,390' - 10,406' Fired 2 G-4 10,406' - 10,420' Top 5' Fi red Run #2 stuck in tbg. at 3,480' while POOH. Cable parted. R.D. Plan fishing procedure. Note: 20 days spent attempting to retrieve fish. successfully cleared utilizing coiled tbg. On 10/23/93 tbg. was 11/2/93 RU E-line. PT lubricator + BOPE to 2500 psi - GOOD. RIH w/ 2-1/8" phased expendable, 65PF strip guns. Flowed well to obtain underbalance and perforated the following: RUN BENCH DEPTH (DIL) RESULT I G-4 10,400' - 10,420' Fi red 2 G-4 10,364' - 10,384' Fi red RD. Returned well to production. H: \wp\WELLOPS\D31 RD RECEIVEr [)i{C 1 7 199~i .~ u,, & G~s Cons. Anchorage 1. Type of Request: STATE OF ALASKA ALA,.%'tc, A OIL AND GAS CONSERVATION COMIV3~SION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re enter suspended well Alter casing __ Repair well__ Plugging -- Time extension Stimula-'~'e-'~C · Variance Change approved program Pull Tubing -- ~erforate X Oth"~'r 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service Leg A-1 Cond. #11 Dolly Varden Platform 4. Location of well at surface 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEE, 406' FNL, Sec. 6-8N-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 12. Present well condition summary Total Depth: measured true vertical 1 0,630' feet Plugs (measured) 9,101' feet 6. Datum elevation (DF or KB)'¢~I~'''. 106' KB above MSL ~'~eet 7. Unit or Property name Trading Bay Unit 8. Well number D-31RD 9. Permit number/approval number 76-74 10. APl number 50- 733-20215 11. Field/Pool G-Zone None Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 10,593' feet Junk (measured) 9,071' feet Length Size Cemented 2,492' 13-3/8" None Measured depth 2,492' 10,630' 9-5/8" 2,200 sx 10,630' G-2 10,246' - 10,272' MD G-3 10,315' - 10,335' MD G-4 10,366'- 10,426' MD 8,745'- 8,797' TVD 8,833' 8,851' TVD 8,877' 8,928' TVD True vertical depth 2,386' 9,101' 13. Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model Rh-1 Packer (~10,042', Camco TRBV @ 322' Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation Sept. 2, 1993 If proposal was verbally approved Blair Wondzell Name of approver 9/1/93 Date approved 15. Statis of well classification as: Oil X Gas Service Suspended 17. I hereby ce~fy that ~ foregoing is true and corr~ct.,to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ~ Approved by order of the Commision Form 10-403 Rev 06/15/88 Subsequent form required 10- ~ d ~ Original ~_--. ~gned By David W .Johnston Approved Copy Returned ]ApprovalNo. ~ :~',- Commissioner Date SUBMIT IN TRIPLICATE PROCEDURE D-31RD · e e · · e Obtain a well test w/ 4 W.C.'s. Test tree valves and ensure operational and holding. Conduct safety/environmental meeting. Ensure adequate lighting for night operations. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. RU E-line unit. Hook up platform PA system in unit. lubricator and BOPE to 2500 psi. Pressure test NOTE: Prior to arming guns and until guns are 1,000' in the hole, notify logistic support and complete the safety checklist. Recomplete the safety checklist when guns are ~ 1,000' when POOH. SI well. RIH with 2-1/8" retrieveable strip guns, 4 SPF, phased. Open well. Perforate the following intervals underbalance: RUN BENCH INTERVAL (DIL) FOOTAGE i G-4 10,390' - 10,420' 30' 2 G-4 10,362' - 10,390' 28' NOTE: Flow well for clean-up approximately 15-20 minutes after perforating each interval. Shut in well to RIH and POOH. RD E-line. Flow well to group separator at a reduced rate, slowly opening the choke completely over about 4 to 6 hours. Flow well in group separator for 12 to 24 hours. Monitor separator screen for perforating debris. Obtain a well test following clean-up. H: \wp\WLPRO\D31 RD P !99 Gas Gons. comm~sS~.o~ 'Anch'or~.O~ HARATHE]N BIL CBHPANY TRADING SAY UNIT WELL D-31RD Stage coLLar 7077' Comp[e±ed 18/9/76 -- Ali measuremen~cs are RK]~ ~co ~cop oF equlpmen~c. Comp(etlon String'. 322' Camco TRB6 SCSS¥ (2.75" ID). 0'-10,049' 3.5'% 9.3~, SL, N-80 TIo9. 673' 20% 94~, H-40 Cs9 2492' 13-3/8", 61#, K-55, Sea(Locl< Cs9, 10,630' 9-5/8~, 472, N-80/P-110 Csg. Gas ~if± mandre{s are 3,5", USI CF-2 Conventionat Type Latch Port Size Guiberson M-77 N/A 16/64 Guiberson M-77 N/A 16/64 Depth VaLve ;°235' 233P' 2 3516' 3 4706' 4 5799' 5 6701' 6 7486' 7 8209' 8 8802' 9 9302' 10 9712' 11 9966' 12 10,003' 10,042' 10,049' Baker Mode[ L Circ sleeve. Gulberson Model RH-1 pacl<er, Guiberson shear sub w/ bet[ nipple, Zone 6-2 6-3 G-4 G-2 PERFBRATIE]N$ Interval F± SPF 10,246'-10,27P' 26 4 10,315'-10,335' 20 4 10,366'-I0,426' 60 4 Aver-a9e Deviation : 31.8° °Phasing Date 0 10/90 0 10/90 0 10/90 G-3 G-4 Alaska Oil & Gas Cons. Commission',, Anchorage 32' 2-5/8" perF 9un [est 9/28/86 ~op [~ 10,502'. FiR ta99ed ~ 10,536' 4/2/89 P:BTD Q 10,593' Revision Da~e: 11/90 TD ~ 10,630' Revised By: SSL/neF Reasom ReperF Previous Revision: Ta9 .~_)OLLY VARDEN PL~.~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 4' ~1/.1.6 -'.. '5000 psi CHISTMAS TREE POSITIVE CHOKE RE£E VE S E P -~ ~ i99;~ Aiaska 0il .& 6as rjoi~s. OoraBissio,' A.~chorage ~ 2' 5000 psi ]D--- 2' 3000 psi 13 3/8' CASING STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMI~n-~SION REPORT OF SUNDRY WELL OPERATIONS · Operations Performed: Operations Shutdown Stimulate Plugging Pull Tubing Alter Casing Repair Well Perforate X I~,,~/..~ m Other__ '~"~_ 6. Datum elevation (DF or KB) 106' KB above MSL ~i,eet 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory -- Stratig rap hic -- Service -- 4. Location of well at surface Leg A-1 Cond. #11 Dolly Varden Platform 760' FSL, 1,213' FWL, Sec. 6-SN-13W-SM At top of productive interval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-SN-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 7. Unit or Property name Trading Bay Unit 8. Well number D-31RD 9. Permit number/approval number 76-74 10. APl number 50- 733-2021 5 --~1~. le/. 11. Field/Pool G-Zone 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 1 0,630' feet Plugs (measured) 9,1 01' feet 1 0,593' feet 9,071' feet Length Junk (measured) Size Cemented 2,492' 13-3/8" 10,630' 9-5/8" 2,200 sx measured G-2 10,246' - 10,272' MD G-3 10,315' - 10,335' MD true vertical G-4 10,366' - 10,426' MD Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model Rh-1 Packer @10,042', Camco TRBV @ 322' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure None None Measured depth True vertical depth 2,492' 2,386' 10,630' 9,101' 8,745' - 8,797' TVD 8,833' - 8,851' TVD 8,877' - 8,928' TVD Al~$k~ Oil & G~$ ¢on$, Oornmission Anohomg~ 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 5/2/93 827 455 47 1080 Subsequent to operation 5/16/93 928 435 45 1060 160 160 ! 15. Attachments I 16. Status of well classification as: I Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas Signed ----,,-- --""- Title '~t{,.,(,., k~k,~ ~ Suspended Service SUBMIT IN DUPLICATE~_~ Form 10-404 Rev 06/15/88 DAILY ~ELL OPERATZONS D-31RD 5/4-5/93 Held safety/environmental/operational meeting. RU on wellhead. Lock open SCSSV w/ the auxiliary pump at 4000 psi. Pressure test lubricator to 2500 psi. Good test. RIH w/ 2-1/8" phased enerjets, 6 SPF, 45° phasing. Flowed well to obtain underbalance and perforated the following intervals: Run Zone Interval Length Result 1 G-4 10,400' - 10,420' 20' Fired 2 G-4 10,380' - 10,400' 20' Fi red 3 G-4 10,362' - 10,380' 18' Fired RD. Turned well over to production. 5/11-12/93 Held safety/operational meeting. RU on well. Lock open SCSSV w/ auxiliary pump at 3800 psi. Pressure test lubricator to 2500 psi. Good test. RIH w/ 2-1/8" Enerjets. 6SPF. 45° phasing. Flowed well to obtain underbalance and perforated the following intervals: Run Zone Interval Length Result 1 G-3 10,315' - 10,335' 20' Fired 2 G-2 10,252' - 10,272' 20' Fired 3 G-2 10,246' - 10,252' 6' Fired RD. Returned well to production. H: \wp\WEL LOPS\D31 RD RECEIVED MAY :! ,5 199;~ AJaska Oil & Gas Cons. CommiSsiO~ Anchorage STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMT~SION APPLICATION FOR SUNDRY APPROVALS ·Typeof Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casin-'~' Repair w'~' Plugging -- Time extension Stimula'~' Change approved program -- Pull Tubing ~ Vadance -~rforate X Oth'~' 2. Name of Operator J 5. Type of Well: . . ,, 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company-Sub-Operator) i D~=v~e~o,,p,=m+:~ ~ 106' KB above MSL feet 3. Address J Stratigraphic -- 7. Unit or Property name I P. O. Box 190247 Anchorage, AK 99519 ~ Service ~ Trading Bay Unit 4. Location of well at surface Leg A-1 Cond. #11 Dolly Varden Platform 8. Well number ec. j V At top of productive interval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM At effective depth ~'~"¥ - 7 993 1,154' FEL, 406' FNL, Sec. 6-8N-13W-Sl~aska Oij & Gas Cons. Commissiof~ At total depth Anchorage 11. Field/Pool 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM G-Zone 12. Present well condition summary Total Depth: measured true vertical 1 0,630' feet Plugs (measured) 9,1 01' feet D-31RD 9. Permit number/approval number 76-74 10. APl number 50- 733-2021 None Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10,593' feet 9,071' feet Length 2,492' 13-3/8" Junk (measured) Size Cemented 10,630' 9-5/8" 2,200 sx measured G-2 10,246' - 10,272' MD 8,745' - G-3 10,315' - 10,335' MD 8,833' - true vertical G-4 10,366' - 10,426' MD 8,877' - None Measured depth True vertical depth 2,492' 2,386' 10,630' 9,101' 8,797' TVD 8,851' TVD 8,928' TVD 13. Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model Rh-1 Packer (~10,042', Camco TRBV ~ 322' Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation Ma, 2, 1993 If proposal was verbally approved Blair Wondzell Name of approver 4/30/93 Date approved 15. Statis of well classification as: Oil X Gas Service Suspended 17. I hereby c~th~h~cOrrect tO the best Of my know~edge' ' ~ Signed Title ~LCt t'~ (~ f~ ~q6C-- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test__ Location clearance ~ Mechanical Integrity Test m Subsequent form required 10- Approved by order of the Commision Original Signed By David W. johnston Form 10-403 Rev 06115188 Date ,,.~. --/dj - ¢..2~ SUBMIT IN TRIPLICATE ~), PROCEDURE D-31RD · e · · e e Test tree valves and ensure operational and holding· Conduct safety/environmental meeting. Ensure adequate lighting for night operations. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. RU E-line unit. Hook up platform PA system in unit. lubricator and BOPE to 2500 psi. Pressure test NOTE: Prior to arming guns and until guns are 1,000' in the hole, notify logistic support and complete the safety checklist. Recomplete the safety checklist when guns are La 1,000' when POOH. SI well. RIH with 2-1/8" strip guns, 6 SPF, 45° phase. Perforate the following intervals underbalance: Open wel 1. RUN BENCH INTERVAL (DIL) FOOTAGE 1 G-4 10,400' - 10,420' 20' 2 G-4 10,380' - 10,400' 20' 3 G-4 10,362' - 10,380' 18' Test well 24 hours prior to reperforating G-2 or G-3. If rate exceeds 950 BFPD, RD SWS. Otherwise, continue perforating upper intervals. 4 G-3 10,315' - 10,335' 20' 5 G-2 10,252' - 10,272' 20' 6 G-2 10,246' - 10,252' 6' NOTE: Flow well for clean-up approximately 15-20 minutes after perforating each interval. Shut in well to RIH and POOH. RD E-line. Flow well to group separator at a reduced rate, slowly opening the choke completely over about 4 to 6 hours. Flow well in group separator for 12 to 24 hours. Monitor separator screen for perforating debris. Obtain a well test following clean-up. H:\wp\WLPRO\D31RD MAY -. 7 199, A!aska Oit & Gas Cons, Commission Anchorage DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4"1~';1.6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE RECEIVED AJaska Off & Gas Cons. Coml~,ission Anchorag~ ---- 2' 5000 psi -- 2' 3000 13 3/8' CASING MARATHDN OIL CDMPANY TRADING BAY UNIT ~/ELL D-3iRD 7077' Completed 12/9/76 ALI MeasureMents ore RKB to top oF equipMent. CoMpletion Strlng: 388' COMCO TRB6 SCSSV (8.75' ID). 0'-10,049' 3.5', 9.3~ SL, N-80 Tbs. 673' 20', 94~ H-40 Csg 2492' 13-3/8', 61~ K-55, Se~LLock Csg. 10,630' 9-5/8', 47#, N-80/P-110 Csg. O~s lift mcndrets are 3.5', USI CF-2 Conventlono/ Deoth VO~V¢ ~ 2235' 1 2338' 2 3516' 3 4706' 4 5799' 5 6701' 6 7486' 7 8209' 8 8808' 9 9308' 10 9712' 11 9966' 12 Tyoe Lotch Port Size Gulberson M-77 N/A 16/64 Guiberson N-77 N/A 16/64 10,003' 10,042' 10,049' Boker Model L Clrc s~eeve. Guiberson Model RH-i p~cker. Guiberson she~r sub w/ bell nipp~e. Zone G-2 G-3 G-4 PERFORATIONS Intervol Ft SPF 'Phasing D~te 10,246'-10,872' 86 4 0 10/90 10,315'-10,335' 20 4 0 10/90 10,366'-10,426' 60 4 0 10/90 G-2 Avercge Devi~tion = 31.8' G-3 Alaska OJj & Gas Cons. Commission G-4 32' 2-5/8' perF gun lost 9/28/86 top 8 10,502'. Fitl togged 8 10,536' 4/2/89 PBTD 8 10,593' TD 8 10,630' Revision Date, 11/90 Revised By: SSL/neF Reason, ReperF Previous Revision: Tog ' 1. Operations Denormea: STATE OF ALASKA AL. A OIL AND GAS CONSERVATION COMMI, .)N REPORT O.F SUNDRY WELLOPE ,ATIONi Ooerat~on shutdown __ Stimulate __ Plugging ~ Perforate Pull tub,ng __ Alter casing __ Repair well __ Other __ L 2. Name of Operator UNOCAL (Marathon 3. Address P. 0. Box 190247 Oil Company - Anchorage, AK 4. Locat,on of well at surface Leg A-1 Cond #11 i 5. Type of Well: . Sub lOpe rat O~looment ~ / Exploratory __ ri .~ n Stratigraph,c __ 99 ] z v Service __ Dolly Varden Platform 6. Datum e,l,e,.,vatiqn (DF or, t~,~) 106' Rb~ above M::)L feet 7. Unit or ProDe~vname lraal ng~ay unit 8. Well numoer D-31RD 9. _Pe~rrn_~t.number/approval number /b-/q/92-141 10. APl numOer so- 773-20215-01 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568 FHL, Sec. 6-8H-13w-sr4 At effective depth 1,154' FEL,.. 406' FHL, Sec. 6-8N-13W-SN At total depth 1.150' FEL, 395' FNL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured feet true vertical 10,6 3 0 ' feet 9,101' Effective oep[h: measured feet true vertical 10,5 9 3 ' feet 9,071' Casing Length Structural Conductor Surface Intermediate 2,492 ' Production 10,630 ' Liner 11. Field/Pool 6-Zone Size Plugs (measured) Junk (measured) Cemented None None Measured depth True vertical depth 13 3/8" 9 5/8" 2,200 sx 2,492' 10,630' 2,386' 9,101' Perforation depth: measured true vertical G- 2 G-3 G-4 Tubing (s~ze, grade, and measured depth) I Pa'~ck~/s~a~d ~J~':~L,0(¢e ~l~d ~agsured depth) Guiberson Nodel RH-1 Packer 13. Stimulation or cement squeeze summary Intervals treated (measure(t) 100246' - 10,272' MD 10,315' - 10,335' MD 10,366' - 10,426' MD @ 10f042', Camco TRBV @ 322' 8,745' 8,833' 8,877' - 8,797' TVD - 8,851' TVD - 8,928' TVD RECEIVED Treatment description including volumes used and final pressure 14. Representative Daily, Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Priorto well operation 630 ,-' 514 24 1070 200 Subsequent to operation 978 349 28 1080 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 160 Service DAILY WELL OPERATIONS D-31RD 5/12/92 Safety meeting. Pressure test lub to 2500 psi. Test good. Established CBO. MU & armed 6 SPF AL strip, 45-phase, 0 offset. RIH. Flowed well to obtain underbalance & perforated the following intervals: RUN #1 G-4 10,400' - 10,420' Fired 5/13/92 RUN #2 G-4 10,380' - 10,400' Misfired #3 G-4 10,380' - 10,400' Fired #4 G-4 10,362' - 10,380' Fired 5/14/92 RD. Returned well to production. H:\wp\WELLOPS\D31RD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM APPLICATION FOR SUNDRY 1. Type of Request: Abandor'~ __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator ] 5. Type of Well: ~ . ,,! _ Dcvelopment~ IINOCAI (Marathon {)il Company - .,,ui) t~eratorJ~xploratory__ 3. Address ' ! Stratigraphic __ P. 0. Box 190247 Anchoraqe, AK 991519 Service__ Operation shutdown ~ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate __ Perforate ~ Other __ 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 4. Location of well at surface Leg A-1 Cond #11 Dolly Varden Platform 760' FSL, 1.213' FWL, Sec. 6-8N-13W-SM At top of productiv~ inte?val 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM At total depth .1..¢150' FEL, 395' FNL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth' truemeasuredvertical 10, 630 ' feetfeet Plugs (measured) 9,101' Effective depth: measured feet Junk (measured) true vertical 10,593 ' feet 9,071' Casing Length Size Cemented Structural Conductor Sudace 2,492' 13 3/8" Intermediate Production 10,630' 9 5/8" 2,200 sx Liner 8. Well number feet ,, D-31RB 9. Permit number 76-74 10. APl number 5o- 773-20215-01 11. Field/Pool 6-Zone ~one ~iaska Oil & aas Oons. Anchorage Measured depth True vertical depth 2,492' 2,386' 10,630' 9,101' Perforation depth: measured true vertical G-2 10,246' - 10,272' MD 8,745' G-3 10,315' - 10,335' MD 8,833' G-4 10,366' - 10,426' MD 8,877' Tubing (size, grade, and measured depth) - 8,797' TVD - 8,851' TVD - 8,928' TVD Pa&ef~//a:~d S~¢&pC-e a~I9 hq0ea~ured depth) .6uiberson Mode] RH-1 Packer 8 10,042', Camco TRBV 0 322' 13. Attachments Description summary of proposal - Detailed operations program BOP sketch I4. Estimated date for commencing operation 5/12/92 16. If proposal was verbally approved Blair Wondsel 1 Name of approver 5/14/92 Date approved 15. Status of well classification as: Oil X__ Gas ~ Suspended __ Service 17. I hereby cert!fy that the foregoing istrue and correct to the best of my knowledge. ' FOR COMMISSION USE ONLY' Conditions of apprbval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~¢ 4- Approved by order of the Commission SIGNED BY Form 10-403 Rev 06/15/88 IApproval No.~¢2 / ,,pproved UOpy / - Returned Commissioner Date ~,-- ~- c/.3 SUBMIT IN TRIPLICATE Attachment #1 Well D-31RD Procedure Reperforate G-2, 3, & 4 · e e . · · · e · Skid rig #76 over Well D-31RD. Swap power to rig and ensure drawworks are operational. Hold operational meeting with Otis and operators. RU wireline unit. Install new packoff in wireline lubricator and insure adequate lighting for night operations. Hook up communication system in unit. Secure unit with chains. MU pressure and temp bombs for survey. Pressure test to 2500 psi with waterflood. Pinch well back to 2 rounds open on choke. RIH with pressure bombs and han~ off 10,335'. Open choke full open and let well stabilize. Conduct gas lift survey making stops per attached stop sheet. Interpret data. RD Otis. Evaluate well's performance and point of injection. Call out SWS and conduct safety meeting. RU E-line unit. Hook up communication system in unit. Pressure test lubricator and BOPE to 2500 psi. Apply 4000 psi control line pressure to the TRFV (SCSSV) with auxiliary pump and monitor for any leakoff prior to RIH and during perforating. Pump to be located near lower wellroom entry door. NOTE: PRIOR TO RIH MAKE SURE WELL IS PINCHED BACK TO ONE OR TWO TURNS OPEN ON CHOKE~ KEEP WELL PINCHED BACK UNTIL THE PERFORATING GUN IS BELOW THE TUBING TAIL. PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE, NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATION BLACKOUT. RE-ESTABLISH COMMUNICATION BLACKOUT WHILE POOH. RIH with 2-1/8" strip guns, 6 SPF, 45-degree phasing, offset 0 degrees and perforate the following intervals underbalanced (well flowing). Open choke and stabilize flow prior to perforating. RECEIVED Alaska Oil & Gas Cons. Commission ~mchorage Well D-31RD Procedure-- Reperforate G-2, 3, & 4 Page 2 Run Bench Interval DIL Footage i G-4 10,400' - 40,420' 20' 2 G-4 10,380' - 10,400' 20' 3 G-4 10,362' - 10,380' 18' Test Well 24 hours prior to reperforating G-2 or G-3. If rate exceeds 900 BFPD, RD SWS. Else continue perforating upper intervals. 4 G-3 10,315' - 10,335' 20' 5 G-2 10,252' - 10,272' 20' 6 G-2 10,246' - 10,252' 6' **Flow well for clean-up approximately 15-20 minutes after perforating each interval. Prior to POOH, pinch well back again. Shut in well to POOH (and RIH) if heading appears to be a problem. 10. RD E-line. Flow well to group separator at a reduced rate, slowly opening the choke completely over about 4 to 6 hours. Flow well in group separator for 12 to 24 hours, obtaining WC's every four hours. Monitor separator screen for perforating debris. ~oe63~45.doc RECEIVED MAY 2 8 3992 Alaska Oil & Gas Cons. Commissio~ Anchorage 3-.t12", 9.3'.:, Si, ~2' - tO,g49' 2. 732 - 2,752' - S,]66' Stage Collar 7,O77 __ 9-5/8", &7~7, BUiI, P-ilO, 8,366' - !0,630' TBU Well D-31RD At'taci]men t ~g (.Completed 12/9/76) _ ~L %.99Z 2.75 2,235 3.O0 2,332 3.00 3,516 3.00 4,706 3.00 5,799 3.00 6,701 7,486 3.00 8,209 3.00 8,802 3.00 . 9,302 3.00 9,712 3.00 9,966 3.00 '.:7. ::7.;77; "~ - 10,003 2.81 - 10,042 3.00 32' 2-5/8" perforaeing gun Lost 9/28/86 Top at 10,502' Floa¢ Shoe 10,049 2.992 G-2 Perforations G-3 Per rotations G-4. Per rotations Baker Model L' Circulating Sleev~ Guib. Hode! RH-1 Packer Guib. Shear Sub wi:h Bell Nip'pie 10,246 - 10,266 ~IL 10,315 - 10,230 DIL 10,366 - 10, 'RECEIVED 10,534' Fill 9/26/86 -10,593 PBTD & Gas Cons. C~mmissio,, Anchorage WLB 12/3/86 Attachment.~i~ 3 .. · . ' UOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE , GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4'~1)'.-1.6~.'5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi ~ 2' 3000 psi 13 3/8' CASING STATE OF ALASKA AEA'S~ OIL AND GAS CONSERVATION COM M]'~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging __ Perforate X Pull tubing m Alter casing ~ Repair well __ Other __ I 5. TypeofWelh I ve~, Der Iopment X 0il Company - Subl0perato~'~toratory__ ! Stratigraphic __ Anchorage, Al( 99~19 Service__ Leg ^-1 6ond #11 Dolly Varden Platform FWL, Sec. 6-8N-13W-$M FNL, Sec. 6-8N-13W-$M FNL, Sec. 6-8N-13W-$M FNL, Sec. 6-8N-13W-SM 10,6 3 O' feet feet 9,101' 2. Name of Operator UNOCAL (Marathon 3. Address P. 0. Box 190247 4. Location of well at surface 760' FSL, 1,213' At top of productive interval 1,355' FEL, 568 At effective depth 1,154' FEL, 406' At total depth 1,150' FEL, 395' Size 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: measured true vertical 13 3/8" 9 5/8" 10,593' 9,071' 6. Datum elevation (DF or KB) 106' KB above MSL Z Unit or Property name Trading Bay Unit 8. Well number D-31RD 9. Permit numbedapproval number 10. APl nur~ber 5~)~73-20215-01 11. Field/Pool 6-Zone 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 0~,(::~ ~'~. ~~ Title ~L~ ~'~,,~,..9~ ~"~ ~- ~. ~,\ ,,~,~ Form 10-404 R~~ Prior to well operation 7/8/90 Subsequent to operation 7/31/90 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _.~ true vertical G-2 G-3 G-4 Tubing (size, grade, and measured depth) 3 1/2" N-80 ¢ 10,049' Packers and SSSV (type and measured depth) Guiberson Hode] RH-1 packer 13. Stimulation or cement squeeze summary 16. Status of well classification as: Oil __X Gas __ Suspended __ Casing Length Structural Conductor Surface Intermediate 2,492 ' Production 10,630' Liner Perforation depth: measured 1342 264 61 940 403 234 24 700 feet feet Plugs (measured) Junk (measured) C(~mented 2,200 sx 14. 10,246' 10,315' 10,366' 10,042', 10,272' MD 10,335' MD 10,426' MD Camco TRBV 0 322' Intervals treated (measured) Treatment description including volumes used and final pressure None None Measureddepth True vertical depth 2,492' 10,630' 2,386' 9,101' 8,745' - 8,797' TVD 8,833' - 8,851' TVD 8,877' - 8,928' TVD R O _!VED AUG 2 ? 1990 Oil o Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 110 Service Date SUBMIT IN DUPLICATE feet Attachment #1 TBU Well D-31RD Daily Summary of Well Operations 7/10/90 RU E-line and PT lubricator to 2500 ~si, OK. Made 2 p~rforating runs using 2-1/8" Enerjet III's, 4 SPF, 0 phasing, with 30 offset. Correlated guns with CCL and perforated the G-4 zone 10,390' - 10,420' and 10,366' - 10,390'. Flowed well after each run for cleanup. POOH and RD. \docs\dvp\d31RD. doc RECEIVED AUG 2 7 1990 A~aska Oil & Gas Cons. Gommissio~ ~ ~choraFa STATE OF ALASKA ~ A~ASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon __ Alter casing __ Change approved program __ 2. Name of Operator UNOCAL (Marathon Oil 3. Address P. O. Box 190247 Suspend __ Operation shutdown ~ Re-enter suspended well __ Repair well __ Plugging __ Time extension __ Stimulate __ Pull tubing m Variance ~ f 5. Type of Well: ~_ _..,. _ _~evelopment ~ Company - Sub ,~u~rcl[,uf')Exploratory~ t Stratigraphic __ Anchorage, AK 99 19 Service__ Leg A-1 Cond #11 Dolly Varden Platform FWL, Sec. 6-8N-13W-SM 6-8N- 13W-SM 6-8N- 13W-SM 6-8N- 13W-SM 4. Location of well at surface 760' FSL, 1,213' At top of productive interval 1,355' FEL, 568 FNL, Sec. At effective depth 1,154' FEL, 406' FNL, Sec. At total depth 1,150' FEL, 395' FNL, Sec. 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Structural Conductor Sudace 2,492' Intermediate Production 10,630' Liner Perforation depth: measured 10,630' feet Plugs (measured) 9,101' feet 10,593' 9,071' Size 13 3/8" 9 5/8" feet Junk (measured) feet Cemented 2,200 sx G-2 10,246' - 10,272' MD true vertical G-3 10,315' - 10,335' MD G-4 10,366' - 10,426' MD Tubing (size, grade, and measured depth) Perforate ~X Other 3 1/2" N-80 La 10,049' Packers and SSSV (type and measured depth) Guiberson Model RH-1 Packer La 10,042', Camco TRBV La 322' 6. Datum elevation (DF or KB) ....106' KB above MSL 7. Unit or Property name Trading Ba.y Unit 8. Well number n-~l~n 9. t~ermit number ,16-74 lO. APl number S0--773-20215-01 11. Field/Pool G-Zone ~ ~£?~' 1%~ ~ih l\j~~ J V gu None None Measured depth 2,492' 10,630' 8,745' 8,833' 8,877' 13. Attachments I & 2 Description summaryof proposal__X Detailed operations program 14. Estimated date for commencing operation July 15, 1990 16. If proposal was verbally approved Name of approver Date approved feet J U L 2 0 1990 Alaska 0ii & Gas Cons. O0mmis', Anchorag True vertical depth - 8,797' TVD - 8,851' TVD - 8,928' TVD BOP sketch 15. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signed ,~,-~v--,'~ ~' ' ~ ~-~" FOR COMMISSION U~'ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~¢¢? 2,386' 9,101' Original Signed By David W. Johnston Approved Copy ,Return, ed I Commissioner Approved by order of the Commission J Approval N o. ¢~/~..~.~--~ Date Form 10~403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment ~2 _.)OLLY VARDEN P~.~.TFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) .... LUBRICATOR MANUALLY OPERATED BOP · 4'::.1/~1,'6'-*.. 5000 psi CHISTMAS TREE POSITIVE CHOKE .~ ~---- 2' 5000 psi I , ] { __-- 2' 3000 psi ------- 13 3/8' CASING Well Latest Test/Date Attachment #1 '~,* ~:,, D-31RD Reperforatlng' Procedure 6/28/90 433 BFPD, 7.50 C, 40 BO D Date of Last WL Work 4/2/89 Summary of Work Done 2.70" Gauge ring run, tag fill at 10,536', no scale encountered. Also obtained a FBHP. 1. Obtain a 24-hour well test. . RU E-line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. . Hold operational meeting with platform personnel and E-Line company. Review job in detail and establish responsibilities of work to be performed. e Apply 4000 psi control line pressure to the TRFV (SCSSV) with a hand pump and monitor for any leak off prior to RIH. NOTE: Prior to RIH make sure well is pinched back to one or two turns open on choke; keep well pinched back until the dummy gun or perforating gun is below the tubing tail. 5. Make a dummy gun run to 10,450' (maximum perf gun interval 30'). . Prior to arming guns and until guns are 1000' in hole notify logistic support and establish communications blackout. RIH with 2-1/8" strip guns, 4 SPF, 0° phasing, offset 30o and perforate the following intervals underbalanced (well flowing). Open choke and stabilize flow prior to perforating. Run Bench Interval DIL Footage 1 G-4 10,390' - 10,420' 30 2 G-4 10,366' - 10,390' 24 Test for 24-36 hours: See NOTE below. 3 G-3 10,315' - 10,335' 20 4 G-2 10,246' - 10,272' 26 Flow well for clean-up approximately 15-20 minutes after perforat- ing each interval. Prior to POOH, pinch well back again. Shut in the well to POOH (and RIH) if heading appears to be a problem. Well D-31RD Reperforating Procedure (Continued) · e RD E-1 ine. Flow well to test separator at a reduced rate slowly opening the choke completely over about 4 to 6 hours. Test well for about one week. NOTE: Production profiles indicate that 754 of production is from G-4. Test data to be evaluated by Reservoir prior to perforating G-2 or G-3. Note: Maximum anticipated SBHP is 2600 psi. \docs\dvp\D31RD.doc Unocal North Americ; Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 995t 9-0247 Telephone (907) 276-7600 Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, a~S.~~, u~' ~~~ G sh Regional Drilling Manager GSB/lew DOLLY DISTANCE& DIRECTIONS FROM SE CORNER SEC. 6, TSN, CONDUCTOR "Y" COORD. "X" COORD. WELL # LEG #A-1: LAT = 60o48' 28.272" LONG =151°37' 57.620" 2,490,836.22 1 2 3 4 5 6 7 8 9 10 ll 12 2,490,836.95 2,490,840.99 2,490,842.79 2,490,841.51 .2,490,837.76 2,490,833.28 2,490,830.18 2,490,829.90 2,490,832.58 2,490,835.56 2,490,838.66 2,490,834.00 LEG #A- 2' 2,490,835.42 1 2 3 4 5 6 7 8 9 lO ll 12 2,490,836.16 2,490,840.19 2,490,842.00 2,490,840.72 2,490,836.97 2,490,832.49 2,490,829.39 2,490,829.11 2,490,831.78 2,490,834.77 2,490,837.86 2,490,833.21 LEG r, B-1 · LAT = 60o48, 27. 485" LONG :151°37' 57.564" 2,490,756.22 1 2 3 4' 5 6 7 8 9 l0 ll 12 2,490,755.48 2,490,751.45 2,490,749.65 2,490,750.92 2,490,754.67 2,490,759.15 2,490,762.25 2,490,762.53 2,490,759.86 2,490,756.87 .2,490,753.78 2,490,758.43 LEG #B-2' 2,490,755.43 208,461.20 R13W FSL 757.5 208,454.55 D-27 758.1 208,456.66 D-28 762.1 208,460.79 D-29 764.0 208,465.11' .D-32 762.9 208,467.60 D-40 759.2 208,467.10 D-41 754.7 208,463.83 D-26 751.5 208,459.34 D-25 & RD 751'.1 208,455.72 753.7 208,458.66 D-24 & 34A 756.8 208,462.17 D-31 & RD 760.0 208,462.61 D-24A 755.3 FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 208,381.20 754.7 1132.1 208,374.66 D-1 755.3 208,376.67 D-17 759.4 208,380.80 D-11 761.3 208,385.11 D-7 & RD 760.1 208,387.60 D-9 756.4 208,387.10 D-19 751.9 208,383.84 D-23 748.8 208,379.34 D-21 748.4 208,375.72 ' D-5 & RD 750.9 208,378 66 D-15 & RD.& 2 754.0 208,382.17 D-3 & RD 757.2 208,382.61 D-13 752.5 208,462.00 " 677.5 208,468.53 D-8 & RD 677.0 208,466.53 D'6 672.9 208,462.40 D-14 & RD 671.0 208,458.08 D-20 672.1 208,455.59 D-16 675.8 208,456.10 D-22 680.3 208,459.36 D-2 & A & RD 683.5 208,463.85 D-4 683.9 208,467.48 D-10 681.3 208,464.53 D-12 &RD 678.3 208,461.02 D-18 675.1 208,460.58 D-30 &RD 679.7 208,382.00 674.8 (Reserved for Compressors) 1125.5 1127.4 ll31.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 121'9.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 STATE OF ALASKA '~* i~ !i:~ AL~KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOFI SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company - Sub O~erator~e. vel,°Pm,ent-~- I ~-xploratory __ 3. Address | Stratigraphic m P. 0. Box 190247 Anchorage, AK 99~19 Service__ 4. Location of well at surface Leg A-1 Cond #11 Dolly Varden Platform 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate X Other __ At total deoth, 1,150 FEL, 395' FNL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,630 ' feet Plugs(measured) 9,101' feet 10,593' feet Junk(measured) 9,071' feet Casing Length Size Cemented Structural Conductor Surface 2,492' 13 3/8" Intermediate Production 10,630' 9 5/8" 2,200 sx Liner Perforation depth: measured true vertical 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number B-31RD 9. Permit number 76-74 10. APl number 50-773-20215-01 11. Field/Pool None OCT 2 ? 1989 NonAel Sk Oij Sas Cons, Anchorage ~- Measured depth True vertical depth 2,492' 2,386' 10,630' 9,101' G-2 10,246' - 10,272' MD 8,745' - 8,797' TVD G-3 10,315' - 10,335' MD 8,833' - 8,851' TVD G-4 10,366' - 10,426' MD 8,877' - 8,928' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 e 10,049' P r n S n esu d et) ~~dsSo~~~ ~r~_~ ~tc~trh @ 10,042', Camco TRBV @ 322' 13. Attachments I & 2 Description summary of proposal __~ Detailed operations program __ BOP sketch L 14. Estimated date for commencing operation October' 30, :[989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X_._ Gas __ Service 17. I hereby certify that the foregoing is true and correct to the best of m'/knowledge. Suspended__ Signed .//~¢,/~~~ &~-'_) Title Environmental Engineer · / )' ' 7- k{~.~ "(~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~ Approve~ CoPY Re, ur 5ed ~ Original Sig~ed By ~ ~o Approved by order of the Commission David W. Johns~o~ her Date 10/26/89 lApproval No. ¢~ ¢'¢_7X'~ Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-31RD Reperf/Cla-Sta Treatment Procedure · · 4. 5. 6. 7. 8. 9. RU E-line unit. PT to 2500 psi. Perforate the fRllowing intervals w/ 2-1/8" strip or 2-5/8" hollow carrier guns, 4 SPF, 30v phasing, with the well flowing: Run Interval Footage Zone i 10,390' - 10,420' 30' G-4 2 10,366' - 10,390' 24' G-4 3 10,315' - 10,335' 20' G-3 4 10,246' - 10,272' 26' G-2 RD E-line unit· Bring well on slowly over 12 hours and obtain stabilized test. RU pump equipment, tanks, and chicksan. PT to 4000 psi. SI wel I. Bullhead 1000 gallons, 15>o HCl followed by 63 bbls FIW. Flow acid back (Notify TBPF 24 hours prior to shipping produced acid). Pump Cla-Sta XP treatment as follows: a· 12,000 gal FIW w/ 2>0 Ammonium Chloride, .1>0 Losurf 300, 1.2>0 Cla-Sta XP b. 16,000 gal FIW w/ 2>0 Ammonium Chloride, .1>0 Losurf 300 c. 4,000 gal FIW w/ 2>0 Ammonium Chloride, .1>0 Losurf 300 10. RD pump equipment. 11. Put well in test. Return well to production slowly over 48 hours. Note: Maximum anticipated SBHP is 2550 psi. ~docs~AFE\29.doc Attachment #2 OLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR POSITIVE CHOKE 4' :~1/~1,6'-'., 5000 psi CHISTMAS TREE 2' 5000 psi 2' 3000 psi 1 3 3/8' CASING -~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS'~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing __ 2. Name of Operator ITNOCAL (Marathon Oil Company - 3. Address P. O. Box 190247 Anchorage, AK 4. Location of well at surface Leg A- 1 Cond ¢/11 Repair well __ 5. Type of Well: StJb Oper~m.ent x__ ~xp~ora[ory __ Stratigraphic 9519 Service ~ Dolly Varden Platform Other __ 6. Datum elevation (DF or KB) 106' KB aboVe MSL 7. Unit or Property name Trading Bay Unit 8. Well number 760' FSL, 1,213' FWI,, Sec. At top of productive interval 1,355' FEL, 568 FNI,, Sec. At effective depth 1,154' FEL, 406' FNL, Sec. At total depth 1,150' FEL, 395' FNL, Sec. 6-8N- 13W-SM 6- 8N- 13W- SM 6-8N-13W-SM 6- 8N- 13W- SM D-31RD 9. Permit number/approval number 8-897 10. APl number 50--773-20215-01 11. Field/Pool G-Zone feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,492' Intermediate Production 10,630' Liner Perforation depth: measured 10,630' 9,101' 10,593' 9,071' Size 13 9 feet feet feet feet 3/8" 5/8" Plugs (measured) Junk (measured) Cemented 2,200 sx None None Measured depth 2,492' 10,630' True vertical depth 2,386' 9,101' G-2 true vertical G-3 G-4 Tubing (size, grade, and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model RH-1 Packer 10,246' 10,315' 10,366' @ 10,042', - 10,272' MD - 10,335' MD - 10,426' MD Camco TRBV @ 322' 8,745' 8,833' 8,877' - 8,797' TVD - 8,851' TVD - 8,928' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12 / 2 6 / 8 8 Subsequent to operation 1/08/89 15. Attachment~: ¢/1 Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 746 319 23 1090 891 197 2 860 16. Statusofwellclassific~ion as: Oi1'..%~ Gas__ Suspended__ Service 140 150 17. I , that the foregoing is true and correct to the best of my knowledge. Title E~vironmen~al Enqineer Form 10-404 Rev Roy D. Date 2/2/89 SUBMIT IN DUPLICATE Attachment #1 TBU Well D-31RD Daily Summary of Well Operations 1/4/89 RU E-line and PT lubricator to 2500 psig, OK. Made two perforating runs using 2-1/8" strip guns, 4 SPF, 0° phasing, 30° offset. RIH, correlated and perforated under drawdown, G-4 10,390' - 10,420' and 10,366' - 10,390'. Flowed well 15 min. for cleanup, POOH. 1/5/89 Made two perforating runs using same guns as before. RIH, correlated, and perforated G-3 10,315' - 10,335' and G-2 10,246' - 10,272'. POOH, FD. Bring well on slowly. em/48A/DVP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GeM M Ib"~lON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ 2. Name of Operator UNOCAL (Marathon 3. Address P. O. Box 190247 Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate %__ Other __ Oil Company - Anchorage, AK 4. Location of well at surface Leg A- 1 Cond ~/11 ! 5. Type of Well: S4b 0per~V~,?~ment '1 r-xploratory ! Stratigraphic 99519 Service / Dolly Varden Platform 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-31RD 9. Permit number 76-74 10. APl number 50--773-202:1.5-01 11. Field/Pool G-Zone 760' FSI,, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured true vertical 10,630' feet 9,101' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,492 ' Intermediate Production 10,630' Liner Perforation depth: measured true vertical feet 10,593' ~et 9,071' Size 13 3/8" 9 5/8" Plugs (measured) Junk (measured) Cemented None Measured depth :~,Tr.u¢;,v,c,C. cal depth 2,200 sx 2,492' 2,386' 10,630' 9,101' G-2 10,246' - 10,272' MD 8,745' G-3 10,315' - 10,335' MD 8,833' G-4 10,366' 10,426' MD 8,877' ~bing(size, grade, and measureddepth) 3 1/2" N-80 @ 10,049' - 8,797' TVD - 8,851' TVD - 8,928' TVD PackersandSSSV(tyBeandmeasuredde9th) Guiberson Model RH-1 Packer @ 10,042', Camco TRBV @ 322' 13. Attachments 1 & Description summary of proposal Detailed operations program BOP sketch 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Suspended Service 17. I hereby.,~ertify that the foregoip¢ is true and correct to the best of my knowledge. R~v n_ P~%~ ] ~' FOR COMMISSION USE ONLY Conditions o~approval: NOtify C~mission so ~Kesentative may witness Pug integrity ~" BOP Test ~ Location clearance ~ Mechanical IntegrityTest__ Subsequent form required 10- ~'~' ORIGINAL SIGNED BY Approved by order of the Commission~'0NNIE C. SMITH Approved Copy Returned /C~,,-7~,-"~_ ~'~ Commissioner Date ]_2/0]/88 I Approval No. (~:)._ 2,~'-¢ Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-31RD Procedure 1. RU Electric line. PT to 2500 psi. 2. Perforate the following intervals underbalanced w/ 2-1/8" strip gun, 4 SPF, 0° phasing, offset 30°: Run Bench Interval DIL Footage 1 G-4 10,390' - 10,420' 30 2 G-4 10,366' - 10,390' 24 3 G-3 10,315' - 10,335' 20 4 G-2 10,246' - 10,272' 26 3. RD E-Line. Note: Maximum anticipated SBHP is 2550 psi. em/48A/DVP Attachment ¥)2 D~LLY VARDEN PLA'_T-ORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP 4 1/:.16'-'. 5000 psi CHISTMAS TREE GREASE HEAD (Hydraulically Activated) LUBRICATOR POSITIVE CHOKE 2' 5000 psi ~_-- 2' 3000 psi _------- 13 3/8' CASING STATE OF ALASKA ALASK'A~ OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate:~ Pull tubing Alter Casing [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of wellatsurface Leg A-1Cond #11 Dolly Varden Platfor~ 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM Ateffective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM Attotaldepth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-31RD 8. Approvalnumber 8-560 9. APInumber 50-- 773-20215-01 10. Pool G-Zone Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,492' Intermediate Production 10,630 ' Liner Perforation depth: measured 10,630 ' feet Plugs (measured) None 9,101 ' feet 10,593' 9,071' Size 13 3/8" 9 5/8" feet Junk (measured) feet None Cemented Measured depth True Vertical depth 2,200 sx 2,492' 10,630' 2,386' 9,101' 10,246' - 10,272' MD 10,315' - 10,335' MD 10,366' - 10,426' MD G-2 true vertical G-3 G-4 Tubing (size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model RH-1 Packer @ 10,042', Camco TRBV @ 322' 12. Stimulation or cement squeeze summary 8,745' - 8,797' TVD 8,833' - 8,851' TVD 8,877' - 8,928' TVD Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/6/88 834 227 25 720 130 Subsequent to operation 7/26/88 928 82 19 1100 150 14. Attachment~ #1 Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I,~ereby certify that the foregoing is true and correct to the best of my knowledge Signed /,-~'/~ £ (l -~' '~- z-~:"~ /~"~n~-Title Environmental Eno4 n¢~ Form 10-404 Rev. 12-1-8g"- -) $ /.,7 -' /R.O. Roberts L/ Date 8/15/88 Submit in Duplicate Attachment #1 TBU Well D-31RD Daily Summary of Well Operations 7/15/88 RU wireline, pressure test lubricator, and RIH w/ 2.70" gauge ring prior to reperforating. Tag fill at 10,538' WLM. POOH, RD. 7/21/88 RU E-line, PT lubricator to 2500 psi. RIH w/ 2-5/8" x 20' dummy gun to 10,450', POH. RIH w/ CCL, 2-5/8" hollow carrier gun, 4 spf, 0° phasing to perforate G-4 from 10,396' - 10,420' DIL. Perforating guns had been improperly loaded and the G-4 was perforated from 10,396' - 10,416' DIL and 10,422 - 10,426' DIL. POH, RD and put well in test. 7/22/88 RU electric line, pressure test lubricator, OK. MU 30' of 2-5/8" hollow carrier guns, 4 SPF, 0° phase. RIH, correlate, and perforate G-4 from 10,366' - 10,396' DIL. Flow well 15 min., POOH. RIH w/ 20' of perf guns as above, correlate and perforate G-3 from 10,315' - 10,335' DIL. Flow well 15 min., POOH. MU 26' of perf guns as before, RIH, correlate and perforate G-2 from 10,246' - 10,272' DIL. Flow well 15 min., POOH, RD, place well back on production. NEF/em/48A/DVP STATE OF ALASKA ALASK~OIL AND GAS CONSERVATION COMMFSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon L] Suspend [] Operation Shutdown ~ Re-enter suspended well Eli Alter casing [] Time extension [1 Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-1 Cond ~/11 Dolly Varden Platfor~ 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-31RD 8. Permit number 76-74 9. APl number 50-- 773-20215-01 10. Pool G-Zone 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,492 ' Intermediate Production 10,630' Liner 10,630' feet Plugs (measured) None 9,101 ' feet 10,593' feet feet Junk (measured) None 9,071' Size Cemented Measured depth 13 3/8" 2,492' 9 5/8" 2,200 sx 10,630' JUL 1 5 i',Jask,~ 0it & ?.'*~ ~ feet True Vertical depth 2,386' 9,101' Perforation depth: measured G-2 10,246' true vertical G-3 10,315' G-4 10,366' Tubing (size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model RH-1 Packer @ 10,042' - 10,272' MD 8,745' - 10,335' MD 8,833' - 10,420' MD 8,877' , Camco TRBV @ 322' - 8,797' TVD - 8,851' TVD - 8,924' TVD 12.Attachments 1 & 2 Description summary of proposal:4~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1988 14. If proposal was verbally approved-,_,~,,~'4'd"."¢.,:t....,.,.,+ %Vo:;Jc ~0.~¢,''¢'~]z,. ~ ,,,.,~,~ On Form i~oZ~_ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge .; f/~:,./,C%::.~ ~ Title Environm~n~] ~ngineer Signed i¢, U RO~' D. Roberts Commission Use Only Date 7/ ¢88 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned .4~ LONN'E 6. S~lIH Approved by Commissioner Approval NO. ~ ..~'-~Z' ¢ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicatez¢ Attachment #1 Well D-31RD Procedure to Perforate 1. RU slickline and pressure test lubricator. 2. RIH w/ 2.70" gauge ring and tag fill. POH. RD. 3. RU electric line unit and pressure test lubricator. 4. RIH w/ 2-5/8" dummy gun to 10,450' DIL and POH. 5. RIH w/ collar locator and 2-5/8" perf guns loaded 4 SPF, 0° phasing and perforate G-Zone as follows: Run Bench Interval (DIL) Feet , 1 G-4 10,396' - 10,420' 24' 2 G-4 10,366' - 10,396' 30' 3 G-3 10,315' - 10,335' 20' 4 G-2 10,246' - 10,272' 26' 6. POH and RD electric line unit. 7. Put well back on production and obtain well tests. GDM/em/48A/Sundry JUL ( Well D-31RD Attachment #2 ~LLY VARDEN PLA-~'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 3 1/8' 5000 psi CHISTMAS TREE POSITIVE CHOKE JUL 15 Alaska 0ii & '":.~ .... (?'~ ~. ~}i:~]on ~ 2" 5000 psi __-- 2' 3000 psi 13 3/8' CASING STATE OF ALASKA ALASr~ OIL AND GAS CONSERVATION COMi~'rrSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon f2] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of wellatsurfaceLeg A-i, Cond ~11 Dolly Varden Plat~orn 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM Ateffective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM Attotaldepth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 5. Datum elevation(DF or KB) 106' KB above MSL 6. UnitorPropertyname Trading Bay Unit 7. Well number D-31RD 8. Permit number 76-74 9. APl number 50-- 733-20215-01 10. Pool feet 11. Present well condition summary Total depth: measured true vertical 10,630' feet 9,101 ' feet Effective depth: measured 10,593 ' true vertical 9,071' feet feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor Surface 2,492' 13 3/8" Intermediate Production 10,630' 9 5/8" 2,200 sx Liner Perforation depth: measured G-2 10,246' G-3 10,315' true vertical G-4 10,366' None · ,, ..... ~, ~ ~ ¢ fly N°~aS~ 0il & Gas Cons. Oo~t~issi0 ...... ~ch0rage Measured depth 2,492' 10,630' ~ue Verticaldepth 2,386' 9,101' - 10,272' MD - 10,335' MD - 10,420' MD 8,745' 8,833' 8,877' - 8,797' TVD - 8,851' TVD - 8,924' TVD ~bing(size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV(type and measured depth) Guiberson Model RH-1 Packer @ 10,042' , Camco TRBV @ 322' 12.Attachments~ YJl Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March 1988 14. If proposal was verbally approved Name of approver Date approved ~1~. I hereby certify that the foregoing is true and correct to the best of my knowledge ~Jgnedt- ~~,~))~~ Title Environmental Engineer Date 3/22/88 ~5,(:~¢ D. ~oberts Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance~ .Approved Copy Returned _ ...__.ff__-__/ Approved by ORIGINAL SIGNED BY LONNIE: C. SMITH Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate Attachment # 1 Well D-31RD EDTA Stimulation Procedure 1. RU CTU and pump equipment. Pressure test to 4000 psi. 2. RIH to 10,450' w/coil tubing. Fill tubing and coil tubing with diesel and establish circulation. 3. Circulate in place (across the perfs) the first 30 bbls of EDTA w/10% inflo-40 (mutual solvent). Allow to soak 20 minutes. 4. Close annulus and inject into the formation the remaining treatment as detailed, below. Do not exceed frac pressure. Move coil tubing across all zones throughout job. A. 25 bbls EDTA B. 20 bbls EDTA with 2% FLC-11 (oil soluble resin) C. 25 bbls EDTA D. Displace to top perf w/diesel 5. POH and RD CTU and pump equipment. 6. Unload and test well. PMS/em/654/OE28 STATE OF ALASKA ALASK,__OIL AND GAS CONSERVATION COMIV,~,~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of wellatsurface Leg A-1Cond #11 Dolly Varden Platfor[ 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM Ateffective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM Attotaldepth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 11. Present well condition summary Total depth: measured true vertical 10,630 ' feet Plugs (measured) 9,101 ' feet 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-31RD 8. Approval number 7-1003 9. APl number 50-- 773-20215-01 10. Pool G-Zone None Feet Effective depth: measured true vertical Casing Length Structural 10,593' 9,071' Size feet Junk (measured) feet None Cemented Measured depth True Vertical depth Conductor Surface 2,492' 13 3/8" Intermediate 2,492' 2,386' Production 10,630' 9 5/8" Liner 2,200 sx 10,630' 9,101' Perforation depth: measured G-2 true vertical G-3 G-4 Tubing (size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and S$$V (type and measured depth) Guiberson Model RH-1 Packer @ 10,042' 10,246' - 10,272' MD 10,315' - 10,335' MD 10,366' - 10,420' MD 8,745' 8,833' 8,877' - 8,797' TVD - 8,851' TVD - 8,924' TVD , Camco TRBV @ 322' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data 1/11/88 1/18/88 OiI-Bbl Gas-Mcf WateFBbl Casing Pressure 460 222 14 1040 ps1 1223 288 8 1060 psi ~bing Pressure 120 psi 160 psi 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢ Ro~ D. Roberts Title Environmental Enqineer Date 1/22/88 f Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment #1 TBU Well D-31RD Daily Summary of Well Operations 1/12/88 RU wireline, PT lubricator, and RIH w/production logging tools. Log well, POOH, RD. ]_/13/88 RU wireline, PT lubricator. Made four perforating runs using 2-1/8" through tubing guns, 4 SPF, 0 ° phasing. 1st run: perfed G-4 from 10,396' - 10,420' DIL 2nd run: perfed G-4 from 10,366' - 10,396' DIL 3rd run: perfed G-3 from 10,315' - 10,335' DIL 4th run: perfed G-2 from 10,246' - 10,272' DIL Did not tag bottom. RD, put well on production. NEF/em/48A/Sundry STATE OF ALASKA AL,~ OIL AN D GAS CONSERVATION CO~rrw.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon L3 Suspend [] Operation Shutdown [] Re-enter suspended weld [] Alter casing [] Time extension [_~ Change approved program [] Plugging E3 Stimulate [] Pull tubing [] Amend order [] Perforate 1~ Other [] 2. Name of Operator UNOCAl, (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of wellatsurfaceLeg A-I, Cond #11 DoiLy varden ~lat£or~ 760' FSL, 1,213' FWL, Sec, 6-8N-13W-SM Attop of productiveinterval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM AteffeCtive depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM Attotaldepth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. vv~,i30 ~z~er 8. Permit number 76-74 9. APl number 50-- 733-20215-01 10. Pool G-Zone feet 11. Present well condition summary Total depth: measured true vertical 10,630' feet 9,101 ' feet Plugs (measured) None Effective depth: measured 10,593 ' true vertical 9,071' feet feet Junk (measured) None Casing Length Structural Conductor Surface 2,492' Intermediate Production 10,630' Liner Perforation depth: measured true vertical Size 13 3/8" 9 5/8" Cemented 2,200 sx G-2 10,246' G-3 10,315' G-4 10,366' Measured depth 2,492' 10,630' - 10,266' MD 8,745' - - 10,330' MD 8,833' - - 10,416' MD 8,877' - Tubing (size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) Guiberson Model RH-1 Packer @ 10,042' , Camco TRBV @ 322' True Vertical depth 2,386' 9,101' 8,791' TVD 8,846' TVD 8,920' TVD 12.Attachment~: #1 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation December 1987 14. If proposal was verbally approved Name of approver Russ Douglas Date approved 12/18/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed[/4~ ~ ~). ~c/~ Title ~- ~_~. Commission Use Only Conditions of approval ORIGINAL SIGNED BY Approved by I flldldlF C. ,SMITH Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned = Commissioner I Approval No. ~. ....., /~.~ ~ by order of the commission Date Submit in triplicate ATTACHMENT #1 Well D-31RD Reperforation Procedure 1. Rig up MOC pump-in-sub'~and electric line over D-31RD. 2. pressure test lubricator to 2,500 psi before every gun run. 3. Reperforate the following zones underbal~nced with 2-1/8" guns,~ 4 SPF, 0° phasing. G-2 10,246' - 10,266' 20' 4. Rig down electric line and place w~ll on test. MDC/em/48/Sundry STATE OF ALASKA "~-- ALAS,..,.¢ OIL AND GAS CONSERVATION COMI~_.~SION COMM REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing I-I,~-~-E~G.~_,~. ~ Alter Casing [] Other [] ~S~R'E~._ 2. Name of Operator 5. Datum elevation (DF UNOCAL* 106~ KB above ~G~ 3. Address 6. Unit or Property nam~ P. O. Box 190247 Anchorage, AK 99519 Trading Bay unf~GASST l 4. Location of well at surface Leg A-I Cond #il Dolly Varden Platfor~ 7. Well number 760' FSL, 1,213' FWL, Sec. 6-SN-13W-SM D-31RD At top of productive interval 8. Approval number ~'~"'" 1,355' FEL, 568 FNL, Sec. 6-8N-13W-SM 428 At effective depth 9. APl number 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM 50-- 773-20215-01 .. At total depth 10. Pool 1,150' FEL, 395' YNL, Sec. 6-8N-13W-SM G-Zone 11. Present well condition summary Total depth: measured 10,630 ' feet Plugs (measured) None true vertical 9,101 ' feet Effective depth: measured feet Junk (measured) ,. true vertical 10,593'feet None 9,071' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,492' 13 3/8" 2,492' 2,386' Intermediate Production 10,630' 9 5/8" 2,200 sx 10,630' 9,101' Liner Perforation depth: G-2 10,246' - 10,272' MD 8,775' - 8,797' TVD G-3 10,315' - 10,335' MD 8,833' - 8,851' TVD- G-4 10,366' - 10,420' MD 8,877' -8,924' TVD Tubing (size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV (type and measured depth) R E C E IV E D Guiberson Model RH-1 Packer @ 10,042', Camco TRBV @ 322' 12. Stimulation or cement squeeze summary 2 1986 Intervals treated (measured) Alaska 0il & 6as Cons. Commission Treati~ent description including volumes used and final pressure Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure · Prior to well operation 8/23/~6 608 99 19 810 psig 150 psig Subsequent to operation 9/30/86 1541 513 12 1070 psig 160..psi~ 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ //(~ * Marathon Oil Company - Sub operator ./2 ~' :~ ~ ', ~ " /)~,~,~?/;,/? . Form 1Q..-404~,1 12-1-85 / Submit iJ DUplicate Attachment 1 Daily Report of Operations Well D-31RD September 26-27, 1986 1. RU wireline company and lubricator. 2. RIH w/gauge ring and tag fill @ 10,534' MD. 3. RIH and perforate w/2 1/2" 0° phased guns at 4 SPF at the following intervals: G-2 10,246' - 10,272' DIL G-3 10,315' - 10,335' DIL G-4 10,366' - 10,420' DIL 4. Stuck last perf gun at 10,004' and pulled out of rope socket. RIH and jarred 30' hollow carrier gun loose and left in hole. 5. Returned well to production. MDC/48A/Sundry RECEIVED Alaska Oil & uas ~,o~:s, Oommissio,~ Anchorage STATE OF ALASKA ALAS~,~ OIL AND GAS CONSERVATION COMI,._.cSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon E~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension F3 Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL * 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-i, gond #il polly Varden Platfor~ 760' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,355' FEL, 568' FNL, Sec. 6-8N-13W-SM At effective depth 1,154' FEL, 406' FNL, Sec. 6-8N-13W-SM At total depth 1,150' FEL, 395' FNL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. W~ I_.~ ~r'~e r 8. Permit number 76-74 9. APl number 50-- 50-733-20215-01 10. Pool G-Zone RECE ¥ D !1. Present well condition summary Total depth: measured 10,630' feet true vertical 9,101 ' feet Plugs (measured) None Effective depth: measured 10,593 ' feet true vertical 9,071 ' feet Junk (measured) None Casing Length Size Cemented Structural Conductor Surface 2,492' 13 3/8" Intermediate Production 10,630' 9 5/8" 2,200 sx Liner Perforation depth: ~RS~I G-2 10,246' - 10,266' MD G-3 10,315' - 10,330' rYE) G-4 10,366' - 10,416' MD Measured depth 2,492' 10,630' ~bing(size, grade and measured depth) 3 1/2" N-80 @ 10,049' Packers and SSSV(type and measured depth) Guiberson Model RH-1 Packer @ 10,042', Camco TRBV @ 322' SEP 3 0 1986 AlaSka 0il & Gas Cons. Co:~ Anchorage True Vertical depth 2,386' 9,101' 8,745' - 8,791' TVD 8,833' - 8,846' TVD 8,877' - 8,920' TVD 12.Attachment~ #1 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation September 26, 1986 14. If proposal was verbally approved Name of approver Lonnie Smith Date approved 9/24/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~.~,~ ~ ~/--~?,/~f' Title EnvironmentaI Engineer Commission Use Only Date 9/25/86 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance * Marathon Oil CompanY - Sub Operator /~ -- /Returned - Approved by ~}~ ~";'.';,'.~;~ ' ~.~, ¢,,, ¢~i~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ATTACHMENT #1 Well D-31RD Reperforation Procedure 1. Rig up MOC pump-in-sub and electric line over D-31RD. 2. Pressure test lubricator to 2,500 psi before every gun run. 3. Reperforate the following zones underbalanced with 2-1/2" guns, 4 SPF, 180° phasing - tag fill after first gun is fired. G-2 10,246' - 10,266' 20' G-3 10,315' - 10,330' 15' G-4 10,366, - 10,416' 50' 4. Rig down electric line and place will on test. MDC/em/48/Sundry Dear Mr. Hamilton: Union Oil and Gas r_ ..fion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 February 28, 1977 Mr:" Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Enclosed for your approval are three (3) copies of the Sundry Notices and Reports on Wells form for TBU D-10. Also enclosed is the Well Completion Report for TBU D-31. We have also enclosed two (2) copies of the Sundry Notices and Reports on Wells form for TBU D-31 since it was completed as a producer and not an injector as originally planned. Sincerely yours, '-.,~J !m~ R._ Cal 1 ender Erf~'t. Drlg. Supt. Form ! 02403 REV. 3-10-73 Subml t "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to Orlll or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) 5. APl NUMERICAL CODE 50-13 3-20215-01 LOCATION OF WELL At surface. 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL ii OTHER NAME OF OPERATOR 8. UNtT, F~RM OR LEASE NAME Union Oil Company of California* Trading Bay Unit ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 6247, Anchorage, AK 99510 D-31RD 10. FIELd) AND POOL, OR WILDCAT McArthur River Field 760'FSL, 1213'FWL, Sec. 6-8N-13W-SM ]3. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2 fEB 14. Check Appropriate Box To Indicate Nature of Notice, Re 1]. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE} Sec. 6, T8N , R13W , SM ]2. PERMIT NO. 76-74 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF: MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZlNG ABANDONMENT* CHANGE PLANS (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Original plans for D-31RD as stated on permit to drill form dated 10-11-76 were for completion of the well as a G Zone water injector. On 12-10-76, the work had been completed on the well and the well was production tested for reservoir data prior to completion as an injector. G Zone Perfs: 10,245' - 10,265';'10,314' - 10,329'; 10,365' - 10,415' Test Data: 357 BOPD, 1 BWPD, 328 MCFG, WOR-O, GOR-919 Since obtaining this data, it has been decided to retain this well as a G Zone producer on its present completion. * Marathon Oil Company - Sub-Operator APPROVED BY. TITLE BATE ~ONDITION5 OF APPROVAL, IF ANY~ Appr~ed Re~d See Instructions On Reverse Side' __ , /" I ........ t.'~T' m P. STATE OF ALASKA OIL AND GAS CONSERVATION SUBMIT IN DUPi,ICATE* ', SOo ~)thor lib. COMMITTEE WELk COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL DRY ~ Other b. TYPE OF COMPLE~ON: WELI. OVER ~ EN ~ BACK gESVR. Other 2. NAME OF OPERATOR Union Oil Company of California* · 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99520 4. L0C~TI0S or wELL (Report location clearly and in accordance with any State requirements)* At surface 760'FSL, 1213'FWL of Sec. 6-SN-13W-SM At top prod. Interval reported below 1160'FEL, 620 'FNL, Sec. 6-8N-13W-SM At total depth 800'FEL, 360'FNL, Sec. 6-8N-13W-SM 13. DATE SPUDDED 114. DATF. T.D. RE, A. CFiED I15. DAT]~ COMP SUSP OR ABAND. 20-17-76 I 22-28-76 i 22-10-76 10,6 30 'MD 1 O, 593 'MD aow mm~Y* ~OT^~ TOOLS 9,1 78 ' TVD 9 '! 46 ' TVD All 22. PRODUCING ~NTERVAL(S), OF THIS COMPLETION--TO,P, BOTTOM, NAME (MD AND TVD)' G Zone: Top: iO,114'MD, 8735'TVD Bottom: . lO,590'MD, 9144'TVD 5. AP1 NU~iLICAL CODE 50-133-20215-01 6. I.EASE DF~qlGNATION A.ND SERIAL NO. ADL-18729 ~! ~ 7. 1F INDiA=N, ALLOTTEE OR Ti;JIBENAiVLE 8. UNIT,FAAllVI O1~ Lt~kSE NAME Trading Bay Unit 9. WELL NO. D-31RD 10. FIELD AfqD POOL, OR %VILDCiT McArthur River Field 11. SEC., T., IL, M., (BOTTOM HOLE OBd ECq'IV E) Sec. 6, T8N , R13W , SM 12. plm-WtiVIIT NO, 76-74 ELEVATIONS IDF, RKB, iq.']', GR, ETC)* 17. ELEV. CASINGttEAD 106.2 'KB AMSL ~ 66 ' INTER%'AI.S DR[IA,ED BY l ('AB ,E TOOLS 2'3. WAS D!RECTIONAL , S UH VI::Y MADE No 24. TYPE ELEC.FRIC AND OTHEt% LOGS RUN SP/DIL, BHC/SoniC, GR/Densi ty ! 25. CASING RECORD (Report all strings set in well) 9-5/8" I 47# ! N-80 20'630'MD 12-2/4"[. P-2_LO , 26. LINER lq.E C O lq.D 28, PEI~FORAT'iONS F p RoDUcTIOIhT' OPF2%I TO (interval, size and number) 20'245' - 10,265' 10,314' - 10,329' 20,365' - 20,415' CE>,ILNTiNG P~EC O ILD G Zone Perfs: 30. PRODUCTION 2200 Sx SCi[EEN ibrD) ., i A.R /[oUNT PULLED , ~ PACI;E[~ SEX' (?,'ID) 27. TUBING SIZE [ L)EPTI4r SET (MD~ 3-1/2;' ] 10,050' 1 ,[ 10,042' 29. ACID, ShO-F, F~A~Vt URE, C~'I£NT SQUL~Z2~, ETC. D~I'Ii 1NI'~V.~ (MDi I A2dOUNI' ~}~.&=!Nl)ro["t M,%¢Ei'.i~L USED DAT'E FIRST P!~ODUCTION [ PP~ODUCTION 1V£EIr-[OD (Flowii~g, ~,a~ lift, pumping--size and type of pump) [V~I,;bL [}'I'ATUS (Producing or 12-10-76 ~ Gas Lift I ' Producinq _ DATE 0F TEST, I~OU~S %'EST~ '[CItOI~E SIZE IP~OD'iq FO~ OI~BBL. GAS--AICF. %VATEII--BBL. ] GAS-OII~ ll.'~TIO 02-22-77 ~ 24 I [T~s~r ~m°o ' ~9, TUBING [CA~qG PRESSURE [CALC~T~ OI~BBL, GAS--RICF. ' I 328 gl. OXSPOS,TXO~ Or o*s (Sold, used );'r Iud, vented, e c.) Sold 32. LIST OF ATTACHMENTS None 33. I hereby cepC[f?that the fo_~regoi.~g and attached information is complete and correct as determined from alUavatlable r~c.rds TITLE Dist. n~lg c,,~+ mvr],: ................. SIGNED , ~ ' *(See [,struction~ one Spaces [or Addifiono[ ~ on Reverse Side) 328 1 WATIgR--DBL. [ OIL GRAViTY-A-PI (COlq-R,) I TES~ WI'['NESSIc'D BY . R. McC2e22an * Marathon Oil Company - Sub-Operator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report e~d log or~ all types of lan:Is and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in' any Items 20, and 22:: If this well is completed for separ3tc prc'duction fr©m more than one ~nterYal zone (multiple completion), so state in item 20, and in itc,,; ?? show the top(s), bottom(s) and name (s) (if any) for only the inter¥,~! ret)erred ir~, ~ter~.; 30 ~br~'~tt a separele repor~ (paoe) on this form, adequately identified, for each a¢td~lior~al i~te~ val to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '34. SUMMARY OF' FORMATION TESTS INCLUDIN(; IN'I'E~vAL TE,STED. PHEF, SURE DATA A2q'D B. ECOVERIF~ OF OIL GAS. 35. G~GIC MARK~ WAT~I AND MUD NAME G Zone Perfs: 10,245' - 10~265' , ,, ~AS. 0~ ~U~V~aV.D~,,, 10,314' - 10,329' 10,365' - 10,415' G Zone Top 10,114' 8735' 24-hr Test: 357 BOPD, 1 BWPD, 328 MCFG,.WOR-O, GOR-919 aS. CO~.E DATA. Aq~I'ACII A~ t)~t~CTE~I,) SI:I(')'WS OF OIL, GAS O~ XVAq~. l[ [ GEOPHYSICAL/GEOLOGICAL DATR,-~ TRANSMITTAL LIST FROM: DEPT. MARATHON 0IL COMPANY ISENDER Di~'~- ~echison TO: COMPANY IDATE February 18,, Mr. H. W. Kug!er State ADDRESS ADDRESS P. O. Box 2380 Anchorage, Alaska 99510 Vi & DATE SHIPPED 1977 QUANTITY I each 1 each PLEASE RETURN ONE SIGNED COPY TO THE ABOVE ADDRESS DESCRIPTION TBU D-31 RD 2" blue~ine 2" sepla~ ./ blue ~ne ~Dia 2" blue~~ & 5" ~ine 2" sep.~a & ~" sepia RECEIVEI~ BY 77 DATE Form No. AN-2 Union Oil 'and Gas £ sion' Western RegiOn Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union January 13, 1977 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE' TBUS D-31 RD Dear Mr. Hamilton' Enclosed for your files are two (2) copies of the Monthly Report of Drilling & Workover Operations for the above captioned well. Very truly yours, Jim R. Callender Dist. Drlg. Supt. Encl. cc' Marathon Oil Co. Atlantic Richfield Company USGS - Rodney Smith RECEIVED JAN 1 DIvt~Ion et Oil ami Gas Geneerv~tion Ikvm No. r- 4 RI'.','. 3- 1-70 SUBMIT IN DUPLICATE STATE O'F ALASKA Oil. AND GAS CONSERVATION COMMITTEE OD iTHLY REPORT OF D IILLING AND WORKOVER OPERATIONS OIL WELL CAS E] Water Injection WELL OTtlER 2. NA.ME OF OPERATOR Union 0il Company of California,', 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchoraqe~ AK 99510 4. LOCATION OF WELL 760'FSL, 1213'FWL, Sec. 6, T8N, R13W, SM Leg A-l, NE, Dolly Varden Platform $. APl NUMERICAL CODE 50-133-202~ 5-O1 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 7. IF INDIAN-ALOTTEE OR TRIBE NAME 8. t~NIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-31 RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field I I. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PERMIT NO. 13. REPORT TOTAL DEPTtt .AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY O'IHER SIGNIFICANT CItANGES IN ttOLE CONDITIONS. TRADING BAY UNIT WELL D-31RD - WATER INJECTOR - DECEMBER, 1976 TD as of 12-31-76 10,630'MD 12-O1-76 - 12-10-76 Drld out stage clr & RIH to 10,566'. Drld cmt to 10,572'. Ran gyro from 2500' - 10,5OO'. Ran CBL. RIH w/ Baker pkr & tested csg. Found fluid going out btm. CO shoe jt. Set ret @ 10,593' and cemented w/ 150 sx. Final press 5000 psi. Ran GR, CCL, & CBL-Sig logs. RIH w/ prod pkr, circ slv,& GL mandrels. Set pkr ~ 10,042'. Hooked up flow lines & GL lines & prod well by GL in order to perf under drawdown conditions. Perfd G Zone Benches 2, 3, & 4 (4 HPF).' 10,385' - 10,415' 10,314' - 10,329' 10,365' - 10,385' 10,245' - 10,265' Prod after 10 hrs.' 735 BPD w/ 0% WC. Released rig @ 12 Midnight, 12-O9-76. Marathon Oi 1 Company - Sub-0perator RECEIVED JAN 1 1971 Division of Oil and Gas Conservation 14. ' heleby certify that the (otegoing is /rue and c,,r,~-ct 1 /11 /77 NOTE-Re~rt on this form is required for e~ch calendar momh, r~0ardless of the status of operations, and mu~ bo filed in duplicate with oil a~ ~ ~onso~a~ion ¢ommitt~ by tho 15th of th~ suec~ting month,unl~ o~herwise dir~t~. Union Oil Company r" ';alifornia D~cember 22, 1976 Mr. Hoyle Hami! ton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hami 1 ton: Enclosed for your information are two copies of tile well history and gyroscopic survey for the TBUS D-31 RD Well. Sincerely yours, ~im R. Callender "~'~'--- Dist. Drl§. Supt. cc: Atlantic Richfield Co. USGS - Rodney Smith DATE 12-15-76 Mz-.~--IATRON OIL. Ct::IiViP,-~.N¥ HISTORY OF OIL OR GAS WELL FIELD McArthur River ',YELL NO.~ LEASE ,. Tradi_ng Bay Unit PARISH Kenai Penin- STATE Alaska __COUNTY sula Borouqh BLOCK SEC. 6 TWP 8N R._. 13W M EASUR EM ENTS TAKEN FROM 106' ELEV. MSL f ToP OF OIL STRING .... ELEV. TOP OF ROTARY TABLE .... ELEV.__ GRD. OR MAT ..... ELEV. HISTORY PREPARED BY M. E. Krugh T~TLE Petroleum Eng. ineer I't is of t~e greatest importance to hove a complete history of the well. Use this form in reporting the history of all imporlant operot;ons at the well, together with the dotes thereof,, including size of hole, size and number of bits, complete, description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE ]976 ~o-17 !0-18 ~0-19 10-20 i0-21 }0-22 ]0-23 10-24 WELL HISTORY - TBU ~VELL D-31RD (Marathon AFE 4569) lO,125'TD On 10-14-76, Schlumberger perfd 4 HPF ~ 9536'. Mud was circ to lO,025'PBTD kill well. Finished repairing rig ~ 5:OO AM. Moved onto well. Set BPV in tb9. Removed Xmas tree. 10,125'TD Finished removing Xmas tree. installed ROPE. PU & installed lO,025'PBTD landing jt. Tested BOP to 3000 psi for 15 rain--held OK. Worked pkr free. Cond mud for 3 hrs. POH laying down 3~-" tbg. lO,125'TD LD 307 jts 9.20//, SL tbg. Tbg had parted in a washed out thread lO,025'PBTD on btm of circ slv. Left 1 jt tbg, I Baker RH-1 pkr, 10' sub, & Q nipple in hole. Offloaded 5" DP. PU OS, jars, bumper sub. Running on 5" DP. lO,125'TD Finished PU 5" DP. Engaged fish ~ 9521'. Pulled pkr loose @ 75,000# lO,025'PBTD above string wt. POH. Rec fish & RIH w/ OEDP to 9793'. C&C mud. RU BJ. Mixed 85 sx class G cmt w/ 4% gel, 1% D-31, .4% R-5, 15.5# slurry followed w/ 10 bbls wtr. After dispt w/ 60 bbls mud, mud suction plugged off. Rev cmt out of hole. Repaired mud lines. Mixed 85 sx class G cmt w/ 4% gel, 1% D-31, .4% R-5, 15.5// slurry. Displ to btm --in place @ 6:45 AM. Pulled DP 1000' above Cmt Plug.- WOC. lO,125'TD P0H after plug back to 8477'. Rev circ 1 hr.. Circ through. DP lO ,025 'PBTD 1½ hrs. Closed rams & press to 1000 psi from 1! AM to 6 PH. Held press OK. RIH & tagged cmt @ 9513' w/ OEDP. Set 25,000// on cmt-- held OK. IF~F[~ LD 148 jts 5" -D~"[ ..... ]~n~'alling spool & ROPE. lO,125'TD Check annulus. Had 1000 psi between 9-5/8" & 13-3/8". Bled off'. lO,025'PBTD Mixed & disPl 162 bbls 10.2// mud into annutus. Well dead. RD ROPE. Ran 9-5/8" csg spear & bumper sub. Pulled & worked csg. Worked slips out. Very little stretch in pipe. Worked for 2 hrs. .Ran free point. Pipe free to 2630'.. Cant to work csg. 10,125'TD Finished flanging up ROPE. Tested. RIH w/ Tri-State cutter, jars, 9,513'PBTD bumper sub. Cut csg @ 2630'. PU & recur at 2450'. C&C mud. POH. Broke down tools & removed ROPE. RU spear & PU csg. Removed slips. Flanging up BOPE. lO,125'TD Finished' flanging up ROPE. PU spear & engaged 9-5/8" csg. Pulled & 2,385'PBTD LD 60 jts & 2 cutoff jts. RIH w/ spear, bumper sub, jars, six 8" DC's. Engaged 9-5/8" ~ 2450'. Jarred at 275,000#. Worked fish to 2512". Came free & POH. LD 4 jts & 2 cutoff its. RIH w/ OEDP to 2685'. Mixed 219 sx class G cmt w/ .075% D-31, .0-3% R-5, 16# slurry. Cmt plug in place @'3:35 AM. POH to 1463' & circ. Press to 1000 psi--held press, wac. Well History - Wel[~D-31RD Page 2 10-25 10-26 10-27 10-28 10-29 10-30 10-31 11-01 1-02 11-03 11-04 11-05 11-06 11-07 11-08 11-09 11-10 11-11 11-12 11-13 .11-14 11-15 lO,125'TD WOC. Loaded out csg, Dialog, & Tri-State equipmt. LD extra 2,454'PBTD ~" DP. PU BOPE. Installed tie-down flange. Installed & tested BOPE to 3000 psi. Held OK. Installed wear bushing. PU drlg assy and ran to top of cmt @ 2377'. Drld out Cmt from 2377' to 2454'. 2,633'TD Drld cmt to 2507'. C&C mud. POH. PU Dyna-drill & RI H. Oriented tool & drld from 2507' - 2633'. POH to chg drlg assy. 3,076'TD Finished making up DA & RIH. Reamed from 2507' - 2633'. Drld 12¼" hole from 2633' - 2948'. Tripped to lock up drlg assy. Drld & surveyed to 3076'. 3,950'TD Drld 12¼" hole to 3739'. Made trip for new bit. Instal led new mud pans on drlg nipple. Drld 12¼" hole to 3950'. 4,780'TD Drld to 4612'. Surveyed & POH. Chgd bit & checked BOP's. RIH & drld to 4780'. 5,400 ' TD Drld to 5134'. Surveyed & POH. Chgd bit & checked BOP's. RIH & drld to 5400'. 5,643'TD Drld & surveyed to 5643'. Drawworks motor arced out. Repaired motor. POH & LD tools. PU Dyna-drill w/ 2½° Sub. RtH. 5,806' TD Finished RIH w/ Dyna-drill. Drld from 5643' - 5673'. Quit making hole. POH. PU drlg assy & RIH. Drld from 5673' - 5806'. POH. 5,930'TD POH. LD DA & PU Dyna-drill. RIH & oriented tools. Drld from 5806' to 5900'. Surveyed & P0H laying down DD. PU drlg assy. RIH to- 59001 & drld 12¼" hole to 5930'. 6,333'TD Drld & surveyed to 6220'. POH & chgd bit. RIH & drlg ahead @ 6333'. 6,745'TD Drld from 6333' - 6612'. Surveyed & POH. Chgd bit & RIH. Drld to 6745'. 7,078'TD Drld to 6900'. Made trip. Repaired mud pans 1½ hrs. Drld 12¼" hole to 7078'. 7,240'TD 7,620'TD Drld 12¼" hole to 7159'. POH & chgd bit. £hecked BOP's, cut- drlg line, & RIH to 7159I. Drld to 7240'. Drld to 7388'. POH to chg bit. RIH & drld from 7388' - 7620'. 7,805'TD Drld to 7662'. Surveyed & POH. Ch§d bit & RIH. Drlg ~ 7805'. 8,140'TD Drld to 7862'. Made trip & chgd bit, roller reamer, & 2 stab. RIH & drlg @ 8140'. 8,255'TD Drld to 8140'. Surveyed & POH. Chgd bit & RIH. Pump press was only 1200 psi. POH. Found bad jet. Chgd jets & RIH. Drld to 8255'. 8,490'TD Drld to 8355'. POH & chgd bit & 1 stab. Slipped drtg line & checked BOP's. RIH & drlg 12¼" hole @ 8.490'. 8,718'TD Drld to 8600'. POH & chgd bit. RIH & drld to 8718'. POH to chg bit. 8,818'TD Finished POH. Chgd bit, RR, & stab. Checked BOP's. Slipped drlg line. RIH & .drld to 8818'. Surveyed & POH. Chgd bit & RIH. 8,960'TD Finished RIH. Drld 1 hr. Mud pump went down. Repaired pump & drld to 8960'. Surveyed & POH. Chgd bit. Checked BOP. RIH. 9,183'TD Finished RIH & drld to 9183'. POH to chg bit. Well History - Well D-31RD Page 3 11-16 11-17 11-18 1t-19 11-20 11-21 11-22 11-23 11-24 11-25 11-26 11-27 11-28 11-29 9,440' TD 9,610'TD 9,680 ' TD 9,815'TD 9,863'TD 9,989'TD IO,114'TD 10,265'TD 10,422'TD 10,508'TD 10,593'TD lO,602'TD lO,630'TD lO,630'TD Finished RIH & drld to 9440'. Drld to 9455', surveyed, & POH. Chgd bit, slipped drlg line 90', & RIH. Drlg @ 9610'.. Drld to 9644'. Ran survey & POH. Tested all BOP chokes & mani- fold to 3000 psi--held OK. Chgd RR, stab, & bit &.RIH. Drld to 9680'. Drld to 9748', surveyed & POH. Chgd bit, checked BOP's, & chgd drlg assy. LD 3 DC's & top stab. RIH w/ bit & drld to 9815'. Drld to 9823'. Surveyed & POH. Chgd bit & 2 stab. Checked BOP's. Slipped drlg line 45'. RIH. Hit bridge ~ 3442' CO to 3462'. I~OH. PU 3 DC's & stab & RIH. Found bridge @ 3437'. CO bridge to 3525'. RIH to 9823'. Cond mud & drld to 9863'. POH. PU new bit & RIH. No hole problems. Drld to 9989'. Ran survey & POH. Replaced 1 stab & bit. RIH. Finished RIH. Drld 12¼" hole from 9989' - 10,114'. Dropped survey & POH. Finished trip & chgd bit. RIH & drld to' 10,231'. Made short trip from 10,231' - 2492'. RIH & drld to 10,265'. Drld to 10,422'. Dropped survey & POH. LD 3 DC's & top stab. PU bit & RIH. On btm when kelly spinner jammed. Repaired for 1 hr. On btm d rlg @ 7 AM. Drld to 10,501'. Made short trip. Drld to 10,508'. Surveyed & POH. Measure out of hole. Hole condition good. Finished POH. SLM corrected. Driller's measurement from 10,508' to 10,500'. Chgd bit, checked BOP's, & RIH. Drld to 10,593'. POH to log. Schlumberger ran SP, DIL. Still logging. '. Cont logging. Ran BHC-GR, Sonic-GR. RD Schl @ 2 AM. PU new bit. Bhecked BOP's. RIH & found 30' fill. Washed to btm & drld 12¼" hole to 10,602'. Drld to TD @ 10,630' by 12 Noon. POH to 3200'. RIH & circ. Dropped survey & POH. Chgd rams, pulled wear bushing, & RU to run 9-5/8" csg. Had run 86 jts by report time. Ran 256 jts 9-5/8", Buttress, N-80 & P-110 csg to 10,630'. Baker stage clr @ 7078' float clr @ 10,584,1,~ float shoe @ 10,630'. Ci. rc 1½ hrs. Cmtd w/ ~000 sx Class G cmt,,, 4% gel, 1% D-31, .002% R-5. Bumped plug w/ 2000 psi. Held OK. Dropped bomb--stage clr did not open. Ran sinker bar & opened stage clr. Circ 1½ hrs. No cmt return. Cmtd w/ 1200 sx Class G cmt w/ 4% gel, 1% D-31, .002% R-5. Closed stage clr w/ 2500 psi. Job compl @ 6 AM. WOC 9-5/8" Casing Detail I rem Len_~ From To KB to 9-5/8" cutoff 1 jt 40#, Butt, N-80 68 jts 40#, Butt, N-80 102 jts 47//, Butt, N-80 1 Stage cl r ' 31 jts 47#, Butt, N-80 50 jts 47// Butt P-110 ~-~:'.~,': = :. : 1 jt 47#, Butt, P-IlO · 2 jts 47#, Butt, P-110 I~i',~..~;::,~ ',~i (~:,: ~:~ i :' ~,~. ~, :,,.:::~. ti.,:~,l Float cl r ~{~ .... 1 jt 47//, Butt, P-110 1 Float Shoe 40.20' 29.45' 2712.96' 4295.02' 1.76' 1287.01 ' 2113.43' 19.92' 84.42 ' 1.63' 42.40' 1.80' O' 40.20' 40.20' 69.65' 69.65' 2,782.61' 2,782.61' 7,077.63' 7,077-63' 7,079-.39' 7,079-39' 8,3-66.40' 8,366.40' 10,479.83' 10,479.83' 10,499.75' 10,499.75' 10,584.17' IO,584.17' 10,585.80' 10,585.80' t0,628.20' !0,628.20' 10,630.OO' Well History - Well~'~-31RD Page 4 !1-30 12-01 12-02 12-03 12-04 I2-05 12-06 ]2-07 10,630'TD lO,630'TD 10,630'TD lO,630'TD 10,630'TD lO,593'PBTD lO,630'TD lO,593'PBTD lO,630'TD 10,630'TD 10,593' PBTD Washed up. Set slips w/ 285,000//. Cut off csg. Installed tbg spool. Tested seals to 5000 psi. Installed BOP & testing. Finished flanging up BOP. Tested blind rams & pipe rams to 3000 psi. Checked manifold to 3000 psi--OK. Tested Hydril to 2000 psi-- OK. Instal ]ed wear bushing. PU six 6" DC's. RIH to 7030'. Tested csg to 2500 psi--OK. Started'drlg stage clr.@. 7 AM. Tested cs9 to 2500 psi--OK. Drld cmt from 7045' - 7077'. Drld stage clr & tested to 3000 psi. Bled off to t900 psi in 30 min. RIH to 10,566' & drld cmt to 10,572'. Circ clean & POH. RU Sperry- Sun on sand line. Ran gyro from 2500' - 1. O,500'. RU Schl to run CBL. Schl finished logging. RD Schl. RIH w/ bit & scraper to 7155'. POH & LD HWDP. Made up Baker pkr & RIH. Set @ 7220'. Tested csg beloe pkr to 2500 psi--bled off to 1700# in 5 min. Tested annular space to 2500 psi--OK. RIH to 10,470' & tested below pkr to 2500#--bled to 1500 psi in 5 min. Tested annular space to 2500#--OK. POH. Finished POH. LD Baker pkr. R.IH w/ bit & scraper to 10,612'. Drld out shoe. CO to 10,630'. C&C mud. POH. Made. up Baker Model K ret & RIH. Set @ 10,593'. Tested DP & lines to 5000 psi. Broke down ~ 1 BPM @ 3800 psi. Mixed & displ 150 sx Class G cmt w/ 1% D-31, .002% R-5, 16// slurry. Min press 3800 psi, final press 5000 psi. CIP @ 2:25 PM. Rev out 8 bbls cmt. Started to POH. Finished POH.' LD Baker tools. RIH w/ bit & scraper to 10,593'. C&C mud. POH. RU DA to run GR, CCL, CBL-Sig logs. Finished logging. RD DA & RIH.to 10,593'.. Displ mud w/ filtered Inlet wtr. LD DP & PU prod pkr. PU pkr, circ sly, & GL mandrels on 3½" IPC, SL tbg. Tested to 5000 psi. Had 311 jts in hole @ report time. 3½" Tubing Detail I tern Length From To KB to tbg hgr Cameron tbg hgr & xo (4½"SL to 3½" SL) 9 its 9.3//, SL, N-80 Camco TRB-6 safety valve (2.81" ID valve, 2.75" min ID) 61 its 9.3#, SL, N-80 1 USI 3½" CF-2 mandrel & Guiberson M-77 GLV, 1½" conventional w/ ¼" port (GLV #1) 3 3ts 9.3#, SL, N-80 1. GLV #2, same as above (GLV #1) 38 jts 9.3#, SL, N-80 1 GLV #3, same as above (GLV #1) 38 j ts 9.3#, SL, N-80 1 GLV #4, same as above (GLV #1) 35 j ts, 9.3#, SL, N-80 1 GLV #5, same as above (GLV #1) 29 jts,.9.3#, SL, N-80 1 GLV //6, same as above (GLV #1) 25 j ts 9-3#, SL, N-80 1 GLV #7, same as above (GLV //1) 23 jts, 9.3#, SL, N-80 1 GLV //8, same as above (GLV #1) 19 jts, 9.3#, SL, N-80 · 1 GLV //9, same as above (GLV #1) '~;i~6 its 9.3#, SL, N-80 1 GLV //10, same as above (GLV #1) 13 j.ts 9.3#, SL, N-80 1 GLV #11, same as above (.GLV #1) 8 j ts 9-3//, S L, N-80 40.50 ' 2.13' O! 40.50' 40.;50' 42.63' 279- 56' 42.63' 322.19' 10.93' 322.19' 333- 12' 1901.90' 4.41' 333.12' 2,235.02' 2,239.43' 2,332.44' 2,336.87' 3,516.13' 3,520.54' 4,7O6.35' 4,710.78' 5,799.94' 5,8O4.37' 6,701.86' 6,706.29' 7,486.76' 7,491.19' 8,209.10' 8,2t3.53' 8,802.73' 8,807.16' 9,302.74' 9,3O7.17' 9,712.98' 9,717.39' . 93-01' 4.43' 1179.26' 4.41' 1185.81' 4.43' 1089.16' 4.43' 897.49' 4.43~ 78O.47' 4.43' 717.-91 ' 4.43' 589.20' 4.43' 495.58' 4.43' 405.81 ' 4.41' 248.92' 2,235.02 ' 2,239.43' 2,332.44' 2,336.87' .3,516.13I 3,520.54' 4,706.35' 4,710.78' 5,7'99.94' 5,804.37' 6,70t.86' 6,706.29' 7,486.76' 7,491.19' 8,209.10' 8,213.53' 8,802.73' 8,807.16' 9,302.74" 9,.307.17' 9,7t2.98' 9,7'17-39' 9,966.31' Well History - Well D-31RD Page 5 1 GLV //12, same as above (GLV //1) 1 jt 9.3//, SL, N-80 1 pup jt 9.3//, SL, N-80 Baker Model L. circ slv, 2.81"1D 1 pup j t 9.3//, SL, N-80 1 jt 9.3//, SL, N-80 4.43' 30.83' 2.18' 3.02' 2.05' 30.22 ' 1 pup jt 9.3//, SL, N-80 3.18' Guiberson Model RH-1 hyd pkr, 3.00"iD 6.8t' Guiberson shear sub w/ bell nipple .8t' 9,966.31' 9,970.74 10,OO1.54 10,OO3.75 10,OO6.77 10,OO8.82 10,O39.O4 1 O, 042.22 10,O49.O3 9,970.74' 10,00t.54' 10,OO3.75' 10,006.77' 10,008.82 ' 10,O39.O4' 10,O42.22' 10,O49.O3 ' 10,O49.84' !2-08 12-09 12-10 10,630'TD lO,593'PBTD 10,630'TD lO,593'PBTD lO,630'TD lO,593'PBTD Finished PU SL tbg. Set pkr @ 10,042' & tested to 2500 psi--held OK. Removed BOP & flanged up tree. Hooked up flow lines. Finished hooking up flow lines & gas lift lines. Prod well by GL to perf under drawdown conditions. Perfd G Zone Bench 4 from 10,365' to 10,415'. Prep to perf Bench 3. · RIH w/ gun #3 & pe~fd 10,314' - 10,329'. POH & RU gun //4. RIH & perfd 10,245' - 10,265'. All perfd w/ DA 2.6" carrier gun & drawdown conditions. POH. RD WL tools &.prep to move rig to D-24A. Rig released @ 12 Midnight, Dece;nber 9, 1976. Total G Zone perfs: 10,385' - 10,415' 10,365' - 10,385' 10,314' - 10,329' 10,245' - 10,265' TUB] NG/CASiNG DETAIL · ANC~ORACE DIVISION · Well No. ~-~/_.~ ~/~_. ~.. ' .Date /Z-7-7;~ Set .,, /~ ~21 ¢~o7,/7 97/2,¢2_ 3~.. ?.3. _ . ,,_ , . , ..... . _ ~LV~/Z. ¢'.~3. .. ~qCC.~I q~0.74~ S q~e , ...... ~, ,, . [ 30,83 9e7o.7~ /o,~/,~ ~ ~ 7.3 ~L ,,, ,~- . ......... . ...... . . ......... . ..... . .......... ....... , - _ : . .. ............ - · ..... -- I ....... ,, No. Length From To Size Wt. Thd. Gr. R~. Cond. Remarks TUB 1 NC/CAS I NC DETA1L · · ANCIlORACE DIVISION Well No. No. From 4-.2,~.3 /z~ .93 3~3,1Z Set To Size Wt. 3~. SL 5L Gr. Vr, Z~ _ Cond. . Remarks V~ ) 4-,43 · 4-3, t I .:7.5'/(,., 13 .,-/-7/0.7f '7-'~3I ?-'Af6,76 ?% ?1 4-.43 gzoT.~O ~.20! FZ I'Z.~ ff~ 7./b j 82o Z,'73 5 ?,3 /;,';-77 ?7-20 ,4/-fO /V- yo ZL · / q.3[ TUB I NC/CAS I NG DETAIL ANCHORAGE DIVISION Well No. ~)-3/t~J Set No. Length From ~0 40,,:, To Size Wt. Thd. _ : .~:297'01. 0?9 2 113,43 8/4/[2 42.40 -- i r- S,q-oe. Date_ %), Z: ~ ' Cond. Remarks i t I I £7': ..,r~/~7 -' ' ' t ' I ! ! t I I , I 1 t FOR ii iii i ~ il,l j_ I · OIL C O~rPANY TYPE OF SURVZY: SURVEY DEPTH: FROM 2 LEASE:. .,Trading nay [Init, FIELD: FlcArt?~ur River COUNTY/PARISH._ Gyroscopic Mul%ishot . _ _FT. TO .... 1O~ .. _WELL i,,to. _i,- 31-RD , STATE A t~ s~a DATE. OF SURVEY'_ l)ecemi)er 2 lc276 JOB NO.. OFFICE' Anch or~:[~, A ].aska 27JI-~676, ~ARATHON OIL COMPANY UOLLY VARDEN RD-31 $'CARTHUR RIVER -- ALASKA SPERg.~_,_$UN... ?!ELL. SL .... JE.YI NG ANCHORAGE, ALASKA DATE OF SURVEY DECEMBER 2,.~976 COHPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY DECEMBER ~" ..... 1976 ........................... ~OB-NUHGER SU~216136 KELLY BUSHING ELEV, = ~06,20 FY, TRUE MEASURED VERTICAL ~EPTH .... DEPTH SUB-SEA COURSE COUI~SE DOG-LEm TOT AL VERTICAL INCLINATZON DIRECTION SEVERITY RECTANGULAR COORDINATES DEP TH ............ DE~ ....... MI N ...... -BEGREE'S ....... DE6~ ~ 0-0 ..... NOR TH/SOUTH ....... E-A'S T/WEs T VERTICAL SECTION 0 0,00 75 7~,99 100 9~,99 125 12~.99 150 1~.99 ............. 200 ~9~,99 99 99 99 99 98 225 22~, 250 2~, 275 27~. 500 29¥, ~25 32~. 550 375 37~. 400 599. 98 98 98 -106.20 0 0 o -~1,20 0 20 -6.20 0 21 18,79 0 20 ~5.79 0 30 68.79 0 93,79 O' 50 118,79 0 143.7~ 0 168.79 0 6'5 19~,79 0 ~6 218.78 0 ~0 2q3'~78 0 31 268.78 O 30 293,78 0 15 N O. 0 E 0.00 2,50 N 1.00 E 2.61 N O, 0 E 0,0~ 2-~'5-0--N 1,O'O-E N 17, 0 E 1,02 2,59 N 1.02 E 2.71 N ~3, 0 E 0,38 2.73 N ~,08 E 2.~ N 29. 0 E 0-$'1i 2~85 N i. 15 E 5.0u N 19. 0 E 0.72 5.02 N 1.25 E ~.28 N 21. O E 0,09 5.25 N 1.$1E N 18. 0 E 0~*~2 3.*~4 N --1,38 E N 25, 0 E 0,25 $,64 N ~,46 E 5,82 N 56, 0 E 0,~9 5,83 N 1,57 E N 28, 0 E 0.48 4.33 N 1.91 E 4,65 N 25, 0 E 1.07 q,58 N 2.04 E q.92 N--~7, ..... O' E ..................... O.q3 ................... %,77-N ................... 2-.15 E ....................... 5.1~ N 70, 0 E 1,15 4.89 N 2,32 E N 6~, 0 E 1,01 4.96 N 2,q7 E 5,q8 ~25 475 5OO 525 550 575 600 625 650 675 7O0 779 8N2 98 318.78 0 16 N 55, 98 3~½3,78 0 0 N O. 98 368.78 0 15 S 56, 98 ~93,78 0 16 S 77, 98 ~18,78 O 15 N 77, 98 qq~,78 0 ~6 N 61, 98 ............... 468,78 ............... 0 ........ 5 .............. N'78, 98 q95,78 0 6 S 76, 98 516.78 0 15 S 61, 98 568.78 0 15 S 68. 98 96 85 593,78 0 45 S 1. 672-,76 I 30 ........ 735.65 5 0 N ~. 7 0 N 0 E 0,20 5,01 N 2.57 E 5,58 0 E 1,06 5,05 N 2,62 E 5.6q 0 W 0,99 5,02 N 2.57 E 5.59 O-'-W .................... 0,58 ............... ~.97 N 2,47-E ........................ 5.~ 0 E 2,06 q,97 N 2.q7 E 5''.~ 0 E 0.29 5.01N 2.57 E 5.58 0 E 0,75 5,05 N 2,64 E 5,65 0 W 0,73 5.0q N 2,64 E 5.6~ 0 E 1,52 5,01 N 2,66 E 5.63 0 E 0,22 ~,95 N 2,75 E 5,65 0 W 1.76 ~,89 N 2,75 E 5.58 0 W 2.76 q,71 N 2.69 E 5,40 0 Z 5,55 7.97 N 5.31 E 9,56 o E l .oo N 8.70 E 15.6 SP£RRY-SUM WELL S, ~/EYIrJG CO?II':~AI,~Y AGE 2 ANCHORAGE, ALASKA ~ARATHOr-J .OIL COMPANY DATE OF SURVEY DECEPISER 2, 1976 ~OLLY VA~<DE~,~ R'm-Si COMPUTATION DATE SU~WEL GYROSCOPIC MULTISHOT SURVE~ ~.CAET?tUR RIVER DECEMBER 5, 1976 JOB NUMOER SU5-16156 ALASKA KELLY BUSHING ELEV. = ~06.20 DEPT TRUE SUB-SEA COURSE COURS USED VERTICAL VERTICAL INCLINATION DIRECT H ..... DEPTH DEPTH ........... DEG... MIN ......... DEGRE E DOG-LEG TOTAL ION SEVERITY RECTANGULAR COOP, DINATES VERTICAL ES ........... DEG/iO0 .... NORTH/SOUTH ........... EAST/WEST ......... SECT ION 10 11 12 15 16 ....... 17 18 19 20 2! 22 2~ 2c~ 24 25 26 27 28 29 ~0 32 35 37 ~9~.5~ 892.~ 9 0 N 35. 0 E 2.00 2~.~5 N ........ ~097~i2 99'0'.92 10 15 N 35. 0 E-- i-;~9 1195,28 1089,08 11 45 N 29, 0 E 1,68 5~.69 N ~29a.7, 1186.5~ 1~ 0 N ~2. 0 E 2.5, 7~,85 N 1586.97 ......... Z282.77 ........... 17 ........ 50 ......... 6'~55~"-0 ....E .............. $.51 .............. 96.75'N ........... 2k85,86 1577.66 19 15 N 5~. 0 E 1.77 125.00 N 0 0 0 0 0 0 0 0 0 0 0 0 . 0 0 0 0 0 0 0 0 16.60 E 29.55 25.95 E ~6.26 55,71E 65,28 , 47.06 E 87.{ -~1'.66-'-E ............11k.5~ 79.07 E 146,10 1577.59 Z~71.59 21 50 N 55. 0 E 2.27 15%,68 N 98.80 E 180.90 16'69~79 ~563';'59' 24 0 N 35,'¥~ E 2,%9 183.35-~N 120~'97 .... E 219.57 1760.96 1654,76 2~ 30 N 56. 0 E 0,6% 216,79 N 1%%.82 E 260.65 1851.78 17~5.58 25 0 N ~5. 0 E 0,65 250,87 N 169,15 E ~02.50 zs,z.'sz .......... 18~6'.iz ........ 25 ...... 15 ......... N"5,-'; ...... 0 E ................ 0"~,9 .................. 285.86"N .............. 195-,16--E .............. 2052,75 1926,55 25 16 N 5~, 0 E 0,01 521.2% N 217.0'% E 987,61 212~,10 2016.90 25 SO N 5~, 0 E 0.~ ~56,77 N 2~1.01E ~50.q7 "2215~26 2107,06 ................. 25 .... q5 ......... N--5~', ...... O--E .................. 0-$2q ............... 592,65 N .......... 26.5~'-19-'E .................... q75.7! 2505.45 2197.2~ 25 ~0 N 25~u.55 22%2.S5 25 51 N 55. ~ 95.88 2287 68 2~ 26 N 51 2~8~.87 2~78.67 2~ ~9 N 22. 257N.70 2~68.50 27 28 N 21. 2662.06 2555.86 BO ~5 N 21, ~ ~5 2% N 21, 27~6,79 26q0,~ 285Uo06 2725.86 ~ 50 N 21. 2912.78 .......... 2806.58 .............. 56 ........ ~5 ............... N 21. 2995.21 2889,01 5% 24 N 21, 5077.7% 2971,5~ 5% 22 N 21, 3242.92 5136.72 3~ -25 N 22. 0.~9 'q28.27 N 289.69 E 516.96 0,03 q~5,91 N 302,0q E 538.~9 ~,01 ~65,59 N 313,5~ E 559.57 3.7~ 500.67 N 332.01E 600.52 2,85 5~1,5~ N 5q8.09 E 693,20 ~.28 586,95 N 565.52 E 690.~ 2,6~ 636,52 N 0,~3 688,21N qO~,~9 E 795.53 0~71 7%0,67 N %2%.53 E 850,02 0,1~ 795.52 N %q~,81 E 90~.91 0,0~ 8~6,2% N q65,05 E 959.67 0.11 898,86"N 0 E 0.58 95!.:53 N 505.92 E .1.069.13 ,5325.29 5219,09 Sq. qO N 22. 0 E 0.24 100..5.91 N 527.!6 E 1124.35 39-07, 15 ........... 5,500.95 ................... 35 ..... 27 ............ N ..... 22~ ..... 0 .... E ................. 0'~78 .......... 1057.16 ~ .............. 54'8'-;"68 ..... E ........... 1180.28 .'5488,78 5382,58 35 7 N 22. 0 E 0,53. 1110,72 N 570,32 E' 1236.5:5 3570.22 5~64,02 35 ~9 N 22. 0 E . 0,69 1164,52 N 592,05 E 1293,03 MARATHON OIL COFiPANy DOLLY VARD£N RD-S! ~CARTHUR RIVER ALASKA SPERRY-SUN WELL S~.,VEYING COMPANY AGE ANCHORAGE, ALASKA DATE OF SURVEY DECEMBER 2, 1976 COMPUTATION DATE SUR''~ . . '- ~,~L GYROSCOPIC MULTISHOT SURVE DECEMBER 5, 1976 dOB NUMBER SU5~161'56 KELLY BUSHING ELEV~ = 106,20 FT, TRuE SUB-SEA COURSE COURSE DOG-LEG TOTAL Y;EASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COOF, DINATES UEPTH ....... DEPTH ........ DEPTH DEG .... -RiN ...... DEGREES ....... DE6)i-O"~ ..... NORTH/SOUTH ........ EAST/WEST VERTICAL SECTION N300 389N,9~ 5788.7~ ~5 38 q~O0 ......... 3976;2'i .... 5870;'02 5~ .... ~9 ~500 ~057.59 5951.19 55 ~9 ~600 ~158,~7 q032.27 55 50 ...................... qBO0 ~300.10 ~193.90 ~6 ~ 4900 4580.92 ~27~.72 ~6 5 5000 ...... ~61.71 ......... ~555,51 5'6 8 5!00 ~5~2.~8 ~56,18 56 19 5200 ~622.79 ~516.59 36 58 N 21. 0 E N 21, 0 E N 21, 0 E N 21, 0 E N 21, 0 E N 22, 0 E N 22. 0 E N 22, 0 E N 22, 0 E N 22, 0 E o,Go 1218,86 N 6 O-;"U. 8- ' -i2'79',55 N 63 ,58 0.01' 1527.9t N 655.32 0,15 1382.38 N 676,23 0.01 lq56,79 N 697,12 E 0,60 lq91,12 N 718,52 E OeO1 15q5,39 N 7q0.~5 E 0.38 1599~92--N --7g'f'~8 E-- O,Zq 165q,60 N 78~,57 E 0.01 1709,20 N 806.65 E N 25, 0 E 0.59 1763,6~ N N 25, 0 E 0.18 1818,04 N N 25, 0 E 0.31 1872.76 N 13q9,79 lq06.39 lq65,05 1519.8 1576,1q 1632.89 1689.89 180~.60 1861.9~ 829~13-' E ........... 852.27 E 1977.21 875,50 E 2035,33 5500 ..... q705.1'i ........... q596,91 ............. 36' '3'~ ....... N-"'22-; ..... ~"-E ..................... 0,6i .............. 1927.80 N ............. 898,30 .... E ............. 2093,q5 5qO0 q78~,75 q677.53 56 3 N 22. 0 E O,q~ 1982.66 N 920.~6 E 2151,07 5500 q86~,33 q758,15 56 32 N 25. 0 E 0.76 2037,3~ N 9~5,11 E 2208,82 5600 qgqg,Eg q838.3g 36 q8 N 2q. 0 E 0.65 2092.10 N 966.93 E 2267.30 5700 5025.9~ qglT.7q 58 6 N 28. 0 E 2.75 21q6.71 N 993,60 E 2527,51 5800 510~,3q q997,14 36 q8 N 32. 0 E 2,75 2199,56 N 1025,96 E 2587.8~ 5900 518q,S7 5078.17 35 1 N 59, 0 E q.q7 22q7,08 N 1057.90 E 2qq6.q 6000 5266.q5 5160,25 3q 39 N 39, 0 E 0,56 2291.~7 N 1095,85 E 250~,q0 6100 6200 6500 6qO0 6500 6600 6700 6900 5348.85 52W2,65 5~ 25 N gO. 0 E 0.61 2535,22 N 1129.91E 255~.92 5~3U.95 .............. 552~,75 ......... 35-=-12 ............ N--'qO; .... O"E ................... 0,78 ........... 2578.9~ N ............. 1166.60-5 ..... 2616.80 5512o~9 5~06.29 ~5 30 N ~0, 0 E 0,29 2~2~,26 N 2205.79 E 267q.~ 5595.98 5~87,78 35 21 N ~0. 0 E 0.1~ 2~67.67 N 12q1.05 E 2732.20 5675.68 .......... 5569',~'8 ....................... 55 ......... 5 .......... N-'-ql'; .... 0 E .................. 0.65 ........... 25i!,52 N ............ 1278,~9'"E .............2769,61 5757.60 5651.~0 3~ 5~ N ~1. 0 E 0,18 255~,80 N 1316.12 E 286&,66 583~,k8 5753.28 55 lO N ql. 0 E 0,26 2598.12 N 1553.78 E 2903.77 5921-.'17 581q,97 ............55 ........ 1'7 ......... N--'~I-,--O'-'E ................. 0.11 .......... 26¢~1~65--N ............. 139i;'6'~-'-E .............. 2SG!-.'lk 6002.83 5896.65 35 lq N qi, 0 E O.Oq 2685.22 N lq29oq9 £ 5018.57 SPERRY-SUN WELL S ,VEYING coMPANY .'AGE % ..................................................................................... AD~iOR'A-~E, ALASKA. '~ARATHON OIL COMPANY DATE OF SURVEY DECEMUER 2, 19?6 GOLLY VAR~EF~ F,O-31 COMPUTATION DATE SURWEL GYROSCOPIC MULT.ISHOT SUP, VE ~CCARTHUR RiV~R DECEMBER 3, &ST6 dOB NUMB. ER SU3-i6136 ALASKA KELLY BUSHING ELEV. = ~06.20 FT. TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ~';EASUREO VERTICAL VERTICAL INCLINATION DIRECTION SEVERiTy RECTANGULAR CCORDINATES VERTICAL DEPTH -'- DEPTH ........ DEPTH ~ ............ DEG.. MIN ........ DEGREES ......... DEG/lU.O- ..... NORTH/SOUTH ........ EAST/WEST ......... SECTIOF'~ 7100 6165.81 6059,61 55 39 N ~2, 0 E 0 7200 62~7,06 ......... 6 .... ' ........................ ........... l~O.8u 55 ~0 N ~2'~-'-~-E 0 7300 &328.6~ 6222.~ 35 0 N ~2. 0 E 0 7~00 6~I0.5~ 630~,3~ 55 2 N ~5, 0 E 0 7500 ' 6~92.57 ............638G'.-37 ............ 5~ ..... ~ ......... N--~3. ..... O-E .............. 0 7600 657~.9~ 6~68,7~ 3% 21 N ~5. 0 E 0 ,63 2772.56 N 1505.92 E 3153 .66 2858.66 [4. 1583.62 E 32~9 .57 2900.97 N 1622.59 E 3306 .29 .......... 29~2.79"N ............166i,59-E ..............3362 .38 298k,26 N 1700.06 E 3~18 7700 7800 7900 8000 8100 820O 8300 8500 8600 8700 8800 8900 9000 9100 9200 9500 9~00 9500 9~00 9700 ~00 $~00 lOOOO 10i0 6657,68 655i.~8 5~ 0 N q~. 0 E 0.66 5025.0i N 1738.72 E 3674 67q'0.37 ...... 663~.'17 3i~ 25 --N ~'~--O--'E ............ 0";-~'~ ........ ~065,~5 .... N ........ 1777~78 E 3529 6822,83 6716,63 3~ ~0 N ~4, 0 E 0.08 3106,15 N 1617.08 E 3585 6905,29 6799.09 3% 2~ N ~5, 0 E 0.57 51~6.~9 N 185G.75 E 36%1 6987.59 ............ 668-1-.39 ....... 3~ ..... 5~ ...... M-~5, ....0 .... E .............. O.q3 .............. 3186.66-N ........ 1896.~0-E ................. 3697 70G~.83 6963.65 5~ 51 N ~6. 0 E 0,65 3226.5~ N 1937.~7 E 3753 7152.21 70q6o01 3q 52 N %6. 0 E 0,01 5265.91 N 1978.2% E 5809 723N.66 ........... 7128.k6 ........ 5~ ..... 24 ..... ~ .... N-~6'-' O' E ..................... 0.15 ....... 5505.22 N ............ 20i8'~95'E .............. ~864 7317.20 7211.00 34 21 N ~6o 0 E 0.04 ~544.44 N 2059.57 E 3920 759~.77 7295.57 3~ 19 N ~6. 0 E 0,03 $38~.62 N 2100.1% E 3975 7%82.73 ...... 7576.55 ........ 33'~- 5% .......... N %6.'~0 E ..... 0.7% 3%22o%1 N 21~0.30 E ..... %030 7565.75 7%59.55 3~ 12 N q6. 0 E 0.63 3%61.1% N 2180.%1 E ~085 76q8.71 75%2.5! 5~ ~I N %6. 0 E 0.51 3%99.92 N 2220.57 E %1%0 "7731.85 ......... 7625.65 ............ 55 ....... 4~ ......... N-'~7; ..... 0 .... E ................ 0.57 7814,85 7708.65 $% 0 N 87o 0 E 0,18 7897.91 7791.71 3~ ~0 N ~7. 0 E 0.33 361~.18 7981.55 ................ 7875.55 ................. 52 .... G9 ............ N"'"q. 7o O'-E ................. 0.8~ ....... 5651.56 8085.30 7959.10 39 25 N ~7. 0 E 0.59 81~8.73 80~2.53 33 30 N ~6. 0 E 0.55 5726.77 ....... 825~.19 .............. 6125.99 ................ 3~ ........ 21 ................ N-'~8'~ ...... O'-E ........................ ~.!I ............ 376~,3~ 85!5.76 8209.56 33 !7 N ~8o 0 E 0.06 380!.09 8599.~9 8295.29 55 0 N ~9. 0 E 0.61 5857.52 8~83,~0 ............... 8577.18 ........... 53 ........ 7 ......... N ,8. .... O"E 85.&7.15 8¢~0.95 ~2 55 N ~8. 0 E 5558."16 'Fi ........... 2'2G"0",'8'7 .... E ................ 5576.21N 2301.67 E 4249 4503 %557 ~i0 N 2502,70 E q518 N 25~5.52 ~ N 258q.~6 E ~625 0.55 587~,~6 N 2625.32 E ~678 0,19 5909°92 N 266,5.81 E q73! N 2342.39 E t'~ ........... 2382.~8 E N 2~22.~3 E [4 2q62.~2 E .82 .70 ,12 .0~: . 85 ':38 . .70 ,67 .6:,5 .29 .87 ,35 .72 .55 .30 .iq ,61 ,20 .69 .8i ,S& ,76 ,5! .70 8651.29 85q5.09 52 30 N %9. 0 E 0.68 ~9q, 5.73 N 2706.28 E 4784..2G SPERRY__-.SUN WELL S..VEYING COM_PA!:,!¥. ....................................................................... AGE 5 Af]CHORAGE, ALASKA I'~ARATHON OIL COMPANY DATE OF .SURVEY DECEMBER 2, 1976 DOLLY VAEDEN RD-31 CO~PUTATiON DATE SURWEL GYROSCOPIC MULTISHOT SURVE" ~CARTHUR RIVER .................................................... DECEF~BER 3,-'1976 .................... JOB MUFflER SU3-16~36 ALASKA KELLY BUSHING ELEV, : 106,20 FT, ~RUE ~CASUR~9 VERTICAL DEPTH DEPTH SUB-SEA COURSE COURSE DOG-LEG 'TOTAL VERTICA~ ...... I.f_qCLI_?,!_A_T!QN___D._!REC.TION SEYE~.!T.y ...... RECTA[.JGULAR_ ...... C_0_0_R_DINATES VERTICAL DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST .......... SECTION 10200 8735.76 ~0300 6~20,59 10~00 8905.8~ 10500 8991.55 10550 ............ 903~.20 8629.56 52 15 N ~9. 0 E 0.28 5980.8~ N 27~6.67 E ~8~6.2~ .... 871~".'59 31 ~ N 50. 0 E-- 0;71 w'oi5~25 N 27~6~9-~-E ~867.5~ 8799,6~ 51 18 FI qg, O E 0,67 qoqg,18 N 2826,68 E q958.18 6585.!5 51 9 N 50. 0 E 0,05 ~082 85 N 2866.10 E ~988 4q 8928'00 30 5q N 5~-O--E' 1,1~ qO99,~2~-f~-' 2885~-98--W 5013.25 HORIZONTAL DISPLACEMENT = 5015,25 FEET AT NORTH, ~5 DEG. 8 MIN. EAST AT MD = 10550 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. S[':'EIqP, Y-SLI;'~ WELL S .VEY.i.';.'.IG COF-iPANY ANCtlOP,;\G[, ALASKA ,~C,ARATHOt,I OIL COMPANY DATE OF SURVEY DECEMi3ER 2, F;OLLY YA~.',DE~'..: RD-S1 COMPUTATION DATE SUP,~.'EL GYROSCOPIC ,"qULTiSIqOT ?;CARTHUR RIVER, DECEF~BER 5, 197G dOB ~,iU:"~,i;.~'F~.~ SU"-~ i6t36 ALASKA KELLY BUSHING ELEV, = 106.20 FT. A GL 6 1976 $ U P, V E ALA SK A- K EL'EY-'B'US iq i R ~--E ['E~ ;--~_--~' o 6 ~-2 0 'F T; .............................. !-N TERP O['~T E-D--¥' A'[ U E-S--'F 0 R-- E V E N'--z 0'00-F EET- OF "ME ASU R E O-'-DEP TH ................................................................... TRUE MEASURED ....... VERTICAL DEPTH 'DEPTH SUB-SEA TOTAL ...... VERT! CA'C .... R E'C T ~'~G'U ['~ R ..... CO-ORDINATES ........ M O-L-T V O VERTICAL DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION o ................................. , ......................... 2;50 N o. OD -~oG eo ....... ~-'-oo .... E ................. 0-.-00 1000 998.5~ 892.~ 2~.~5 N 16.60 E 1.~5 1.~5 2000 ~9~2.~ ~aSG.~i 2SS.SS N igS.lS E 57.Ga ~OOO .......... 2850;--06 272~-~86 68 ~2-i-"-N ..... ~04-, 59'- E .......... ~69~-9~ .................... i'1~-~-~'5 5000 ~q6i,71 ~555.5~ $76~,6~ N 829.16 .E- 5~8.28 I89,67 6000 5266,~5 ...... 5160.25 ............... 2291-, ~7-N ...... i09~' 85'~"E ..................7~3,5~ ...................... 7000 608~.q3 5978.2~ 2728,85 N lq67.~2 E 915.56 182,02 8000 6905.29 6799.09 ~1~6.~9 N !856.7~ E 109~¢.70 179.1~ 9000 77~1.85 ...............7625,65 ............. ~-5-~.8:,--!6-'- ' N ......2260.87 E .... ~268,1q ............... ~7~.~3 10000 8567.15 8460.95 ~909.92 N 2665,81 E lq52,8~ 10560 90~q,20 8928.00 4099.24 N 2885.98 E 1515.79 .................. THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ~H'u.~ OIL COMPANY LLY VARDEN RD-31 .... ~CARTHUR RIVER ALASKA SPERRY-SUN WELL SURVEYING COHPANY A N C H ~R'A ~ E'---A LA SKA ~ P N CO,.'~ UTATIO. DATE DECEMBER ..... 3;-lcj7'6 HAGE 7 DATE OF SURVEY DECEMBER 2, 1976 SURWEL GYROSCOPIC F:ULTIS~tOT SURVE dOB NUM~ER'-SUS216i$6 ............................. KELLY BUSHING ELEV. = 106.20 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED VERTICAL DEPTH DEPTH SU-~-:SEA TG'TXL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 6 6.19 1-06 .......... i06,20 206 206,19 506 506.20 ~06 .............. qOG.20 506 506,20 606 605.20 706 .... 706~-20 ..... 606 806.20 906 906.20 -106,20 -100,00 0,00 100,00 200.00 s o-o-~-o o qO0.O0 500.00 GoO, oo 700.00 800,00 1007 ......... 1006. 1109 1106. 1211 1206. 1515 1306. 1~18 14OS. 1525 1506, 20 ........... 900','00 20 1000.00 20 1100,00 19 ........1200'00 20 1300.00 19 1~00.00 2,50 N 2.50 N 2;76 N 3.~9 N ~.97 N ~,97 N 5,0~ N 5.9~ N 15,67 N 25'-~q5"-N 39.70 N 56.68 N 76~77-"N 101.28 N 129.~7 N 1650 1606, 1759 1706. 1,00 E 0,00 1.00 E -0,00 -0,00 $.i'O'-'E ............ 0'.'Oo 0-,'0o 1,qO E 0,00 0.00 1.95 E o.oo o.oo 2.5o E 0-~-o~ o.o-O 2.q6 E O.Ol 0,00 2.6~ E 0.01 0.00 2.69-E 0;-01 0.-00 ~.98 Z 0.05 o.o~ 9.16 E 0.52 o.~G 17;29 E ....... . ............... i. 55 26,82 E ~.02 1.46 36,81E ~,95 1,93 ~8'-89 .... E ..................... 7.68 .......................... 2.73 ............................................... 64.62 E 11,85 4,17 83.q3 E 17.45 5.59 105",26-"E ................ 2q',5~ ........................ 7',09 ....................................... 130,27 E ~3.65 9,!0 2 o ............. 15o o-. 0 o .................... 1'6"o-;' 91 ..... N 20 1600.00 196,63 N ~ARATHO¢'I OIL L~OLLY ¥.A'"""'->U.,:_N ,"';EARTH, UR RIVER ALASKA CO,',PANY RD-3t sEE ~.._P,_Y__-.~..u N_?E L L .... S._U'_?,yF' ~ :T. H G .... C_O.r'LP_A r: Y ANCHORAGE, ALASKA CO'D~PUTAT'~ Or.l [}ATE DECEt-~BER' 3, r'AGE DATE OF SUP, VE¥ DECEMBER 2, !9'76 SURWEL OYF{OSCOPIC ?.'iUL. TISHOT SUEYE' 1976 ........................ 'JOB NUD-i.~ER SU3-i6166 KELLY BUSHING ELEV. = 106.20 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH .................. TP,.uE ............. ¢~EASURED VERTICAL VERTICAL 'DEPTH DEPTH DEPTH ~'O'T~[ RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 18q9 1806 1960 !906 2070 2006 2181 2106 2292 2206 2~05 ........... 25'06 25i5 2406 2625 250~ _ 2755 2606 2851 2706 2971 2806 ~092 2906 3213 3006 ~55 3206 3576 3306 ~695 3~06 _ 5821 3506 39~ 3606,20 ,20 1700.00 235.52 N 156, °20 ZSO0.O0 27Zo74 N 183. ,19 ........... 19o0, oo ..................... ~Zo;~"-N ........ 21o~ .ao 2000.00 550.09 N asa. .20 2100.00 ~89.80 N 263. .20 ........ 220-0';'00 ~2'~-;'35 N 290~' .20 2500.00 .20 2~00.00 509.90 N ~5. .20 ........... 2500.'00 ................... 557,25 N 354'~ .19 2600,00 612,16' N 575, .20 2700.00 675,27 N ~98. .-19 ......... 2500.00 .............. 756'~-~ .... N .20 2900.00 800,5~ N .20 5000.00 86~.~0 N o19 .......... 5100.00 ................... 928,00 .... DJ ................ ,20 5200.00 991.66 N .20 5300, .20 5~00, ~500. ~22. q72. 496~ 522. 9~ E 43,52 9.87 65 E 53.86 10,$3 O'~"a .................... 6~',~ ....................... 10-',56 50 E' 75,07 10.63 29 E 85.95 10,88 ~'--E 96','8G i-b-;gi 35 E 107.52 10.~6 72 E 117.32 9.99 11 E 129,~9 12,17 20 E i~5.5~ i6.0~ 66 E 165o06 19.52 91E ................... 185,80 ........................ 2'0-,-7~ 51 E 207.10 21.29 03 E 228.2~ 21,16 52 E ................... 2~9.28 ............................ 21-;'01 22 E 270.58 21o29 O0 1056.53 N 5:+8o~3 E 292.63 22.05 O0 ........................ 1'1-22';08 -N ............... 57[~ ;'91 .... E ................... 315,'09 .......................... 22;'~6 O0 1188,59 N 60!,7¢, E 358,15 23,06 ~ARATHON OIL COMPANY DOLLY VARDEN RD-51 ~CARTHUR RIVER ....... ALASKA SPERRY-SUN WELL S~KYEYING COMPANY ANCHORAGE, ALASKA COMPUTATION DATE DECEMBER-3, 1976 --PAGE 9 DATE OF SURVEY DECEMBER 2, 1976 SURWEL GYROSCOPIC MULTISHOT SUP, VE O 0 B-- N U FiB E R" -su3 ;;i 61-$ 6- KELLY BUSHING ELEV, = 106,20 FT. MEAS DEPT TRUE URED VERTICAL H DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUD-SEA DEPTH SU'B 2S'E-A T 0 T ~ L VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION q067 ~706.20 ~600.00 6190 5806.19 5700.00 4313 ~906.20 5800.00 ~456 q006,20 5900.00 ~560 4106,20 4000.00 4807 4506.19 ~200,00 ~951 ~q06.20 4500.00 5055 ' ~506'19 ............~qO0-.O0 5~79 4606.20 ~500.00 5503 ~706,19 ~600,00 5427 ............ ~806.20 ..... ~700,00 5552 490&,19 ~800.00 5677 5006.20 4900.00 5805 '- 5106,19 ........... 5000 5926 5206.20 5100 60~ 5506.19 5200 6169 5~06.19 .............. 5500 6292 5506.19 5400 1255,61 N 1522.8~ N i389.9i N 1456.86 N 1523.78 N 159o;'9 N ~658,72 N 1726.28 N 627,57 E 561.28 25.12 655,~7 E 584.50 25.22 679';12 E 407.6~ 70~.82 E ~0.69 25,05 751.72 E ~5~.99 23,29 758.87 E ~77.50 23.51 786.2~ E 501.54 23.83 813.53 E 525.07 25.72 1793'.57--N ......... 84~'~88 1861.q0 N 870.68 1929.92 N 899.15 --1997~82-N 926'59 E 2065,90 N 955.31 E 2134.45 N 987.21 E '-00 .................. 2201';15'-N ..... ~ ..... 1025.11-E .00 2258,97 N 1067.55 E .00 2512,78 N 1111,16 E .00 ...........2365.58 .00 2q19.82 E ............... 5~8.89 .............................. 25.82 E 57~.i~ 24.22 E 597.65 2q.52 ............. 621~58 ................. 23.95 645.92 24.53 671.50 25.57 ............. 697.~5 .................... 26'~05 720.~5 2~.09 7~2.10 21.65 N 1155.58-5 ................. 763.52 ............................. 21~-'~2 ......................................... N 1200.90 E 786.06 22.55 SPERRY-SUH WELL S. ,VEYING COMPANY AGE 10 ANC~ORAGE, ALASKA ~-'~ARATHON OIL COF'~PANY DATE OF SURVEY DECEMBER 2, 1976 GOLLY VAROFM RD-31 COMPUTATION DATE . . SURWEL GYROSCOPIC ¢.iULTISFiOT SU;~VE ?~CARTi-~UR RIVER ................................... DECEMBER 5, 1976 JOB N~JHUER SU3-15!56 ALASKA KELLY GUSiiIt~G ELEV, = 106.20 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~EASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH T-OTAL ..... RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUT~I EAST/WEST DIFFERENCE CORRECTION 6~I~. 5606 6537 5706 . _ 6655 5806 6781 5906 690~ 6006, = 7026 6106 71~9 6206 7272 6~06 7~ff 6~O& 7516 6506.19 76~7 66~6~20 7758 6706.20 7879 6806.20 8001 6906.!9 6122 7006.19 82qq 7106.20 8365 7206,20 6~86 730&.20 8607 7q06,20 .20 5500,00 2~7%.~0 N 12%6,61 .20 5600,00 2527,69 N 1292.56 .19 ......... 5700°00 ...................... 258-0',-~2-'N ......... 1558.59 .20 5800.00 2633.65 N 138~.67 .i9 5900.00 2687.ol N i~si.o5 .20 ..........60'00.00 27~';52'---~ ...... ~'77.57-' .20 6!00.00 279~.89 N 1525.~0 .2o 6200.oo 28~6.98 N i57~.il .19 ............ 6300.00 ........... 2898,'7~--N ....... 1'6-2'~.3i'-- 64.00.00 29~9.70 N 1667,83 6500.00 2999.88 N 171~.63 6600.00 ................. 5048,61 N 1761.52 6700.00 3097.92 N 1809,14 6800.00 51q6.9~ N 1857.17 . _ 6900,00 5195,82 N 1906.06 7000.00 52q~.91 N 1955.~7 7100,00 5291,68 N 200q,93 7200.00 ...................~539.22 .... [4 .......... 205%.16 7~00.00 $~86,67 N 2!0~.29 E 808.77 22.71 E 831.09 22.31 E 85~.07 21.98 E 875,~5 22.37 E 897,92 22.q6 E .................... ~20,50 ................ : ..... 22-;58 E 9~3,~9 22.99 E 966.39 22.90 'E ...................... 988.,9 ............... 22,09 E 1010.37 21.88 E 1051.85 21.27 E 1052,~7 20.71 E 107~.61 21.2~ E 1094,89 21,27 E 1116.~7 21,57 E 1157.95 21.46 E 1159.50 21,36 E 1180.~7 21.17 E 1201,57 21,t0 ;'~^RAT.HON OIL 60P'IPANY DOLLY VAF:.DEN RD-3! hCARTNUR RIVER ALASKA 'SPERRY-SUN WELL S~-.,VEyING CO~'-IPANY ANCHORAGE, ALASKA ~,PUTATION DATE DECEF'.,.BER' ;5~' 1976. AGE 1! DATE OF SURVEY DECEN~3ER 2, 1976 SURWEL GYROSCOPIC ;IULTISHOT SUKVE"F dOB NUF-!SER SU3-161~,6 ............... KELLY BUSHING ELEV. = 106,2.0 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE EEASURED VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTti/SOUTH EAST/WEST DIFFERENCE VERTICAL cORREcTION 872G 7506,20 88S8 7606,20 8~69 ......... 7706~'20 ..... 9089 7806.20 9209 7906,20 9~29 ......... 8006~'20 9448 8106.20 9568 8206.19 9688 8~06 9807 8~06 9~27 8506 10046 8606 ~0165 8706 10283 880~ 10400 8906 10517 10550 7~00.00 5ff55.22 N 2151,50 E ~221.95 7500,00 5~80.20 N 2200.1~ E 12~2.67 7600~00 $526=~'q~ N 2246'50-E 126'2-;~1 7700.00 5572.25 N 2297,~0 E 1285.56 7800,00 3617.9~ N 25~6.~2 E 1~05.75 7900,00 5662-;-,0-'~i ........2-39~i1'0 .... E ....... ~323,i2- 8000.00 5707.26 N 24~2,14 E 8100,00 5752.69 N 2~89.99 E 1~62.67 .19 ............ 8200'-,'00 .20 8500.00 .19 8~00,00 20.E& 20.71 20,~ 20,$8 1'9~-37 19,66 19.88 ---3796";'89'-R ...... 25'58-;86-E .......... 1382.56 .................. 19-;-68 ............. 5840.17 N 2587.75 E 1401,79 19.45 5885.46 N 2656.~2 E 1421.15 19.~5 .19 ............ 8500.00 ............. 3926;79"-N .......... 2684.59 .20 8600,00 5968.62 N 2752.61 .20 8700.00 4009.51N 2780,11 .20 8800,00 ....... ~0~9,$2 N ..... 2826.85 ....... 14~0.29 .................... 19.16 ..................................... 1~58.8~ 18,55 1~76.87 18.02 1~9~.21 17.~q PROCEDURES USE A LINEAR INTERPOLATION BETWEEN 20 FOOT MD {FROM RADIUS OF CURVATURE) POINTS T~IE CALCULATION TIlE NEAREST 9006.20 8900.00 ~088.61N 2872.97 E 1511.1~ 16.92 90S4.20 8928.00 q099.2~ N 2885.98 E 1515,79 q.65 7'~,,'~i',~i~'i ~:~ · 0~ i'~ C A i T i-i':J i'~ R!VER AL ASK A VE['~TiCAL SECT 976 ~'UKV o EY DATE PI~_D ALOr~L~ CLOSUi<F .. SPERRY-SUN WELL SURVEYING COMPANY SUS-16136 RECORD OF SURVEY ......... TROE ............................... fNCLZNATIO~ .......... D'IR£CTION MEARUR'ED VEFITICAL SUB-SEA DEPTH DEPTH DEPTH BEG DOG_-LEG .......................................... p, EC T'ANGULAR SEVERITY VERTICAL COORDINATES DEG/100 SECTION O, 0.00 -106,20 ~4. ~3.99 -52.20 0 1 75. ............. 7~+,99 ............ 3!"'20 0 20 2.50 N N O. 0 E 0.00 2,62 2.51 N N-'1'7'; 0 .....E ............ 1'02 ....................2.80 ........... 2.68 N 1,00 E 1.00 " 1.05~ _ !00, 99.99 -6,20 0 21 N ~. O'E 0.56 2.95 2,8.1 N - _ I85. ............. i24-,-99 ........ iS','79 0 aO N 89-~'-0 ....~- ........ 0.11 ................. S.09 a.9~ N 150. 149,9.9 ~3.Y9 0 SO U i9. 0 E 0.72 :~.~0 ~.1~ N 1.13-E 1.20 E 1.~7 E 175 200 225 , ............. i74-;'99 ........... gS',"79 0 s~ N 2i. 0 E 0.09 s.52 . 199.99 95.79 0 50 N 18. 0 Z 0.12 5.75 5.56 N . 22~.99 118.79 0 51 N 25. 0 [ 0.25 ~.95 3.76 N .. 1.35 E 1.42 E 1.52 E 250 2.75 25OO . 249.99 143,79 0 50 N 36, 0 E 0,39 ~.17 3.94 N . 274.99 168,79 0 q5 N 37. 0 E 1.00 4,50 4,2.0 N , 299.98 195.78 0 46 N 28. 0 E 0.48 4.85 4.50 N 1.64 E 1.8% E 2.00 E 325 350 375 Z24.95 218.78 0 zo N 25. 0 E i.07 '5.04 4.70 N .............. 549.'98 ...... 2'4~';'78 0 51 N-37', .... 0 .... E ............ 0,'-~$ ................... 5'2'7 ~.88-N 57Y.~5 268,78 0 50 N 70. 0 E 1o15 5.45 4.95 N 2.09 E 2 2~ - ~25. 424.98 ~50. 4~9,98 2~3'~"78 .................... 0'"i5 .............. N"'64~ .....O"E .............. i.'O~l ........................... 5;5~ ........................... 5'70-0 ..... N ......................... 2.55 E ~18,78 0 l& N 53, 0 E 0.20 5,65 5.07 N 2.62 E ~,78 0 0 N O. 0 E 1,06 5.65 5.07 N 2,62 £ 475, D, 74,98 500. q, 99.98 550, 5~9.98 575, 574.98 600, 599,98 368.78 0 15 S 56, 0 W 1,00 5,55 5.01 N 2,53 E 393,78 0 16 S 77. 0 W 0,58 5.47 4.98 N 2.42 E 4i8.76-- 0 i5-- N-77;'--O .... E ...... 2';'06 5';"55 5,O0.N 2;52 [ 4~5.78 0 1~ N 61. 0 E 0,29 5,65 5.06 N ~.6~ £ 4.68,78 0 5 --lq 78, 0 ~-- 0.75 5,68 ~0'~ N 2,'66 [' ~9~.'78 0 6 S 76, 0 W 0,7~ 5,6~ 5.06 N 2.62 [ SPERRY-SUN WELL SURVEYIi.,IG COP}PANY 'SU5-16136 RECORD OF SURVEY ........... TRUE ........................ I,",ICLiNATIOf,~ .... DIRECTION -' DOG*LEG ............................................. RECTAi,}GULAR .......... f¢ ¢'"" ,,,. .,= %.. r , , ,.:,A R UF'<ED VERTT!CAL SUB SEA SEVF_RTT¥ VERTI"^L 600RDIrqAI'ES DF,PTH BEPTI4 DEPTH DEG P1ZN DEG PlIl',J DES/1.00 SE(iTION 625, 62q.98 518.78 0 15 S 6!, 0 E 1.32 5.66 5,0! N 2.71 650° 6q9,96 5q3,78 0 16 $ qg, 0 E 0.22 5,6~ q,95 N 2.80 575. ..... 67~.98 ........... 568'78 .............0- 15 .............. S-"68~'--0"W ........... 1.76 ................... 5,55 .................... ~,89 N ............. 2.7¢ 700. 699.98 593,78 0 q5 S 1. O W 2,76 5.28 ~.56 N 2.70 E 779. ...... 1"778'.'95 672.75 - 1 50 N 56-~ 0 E ~ 2.7,,-3 7,55 .............. 8~2, Sql.Ti 755,51 5 0 N 5~. 0 E 5,55 12.8~ 10.79 N 6.98 E soo, ................ 899'.-'28 ............ 79~ ;'08 ............. 7' -0- ............ N '-~-. .... 0 .... E .............. 5'7'4q: ......................... zg', 91 ................. i6T65--N Lo'; ss-'[ 1000. 998.05 89!.85 9 O N 55. O E 2.00 55.55 29.~& N !9.91 llO0. 1096.~5 990.25 10 15 N 55, 0 E 1,29 55.55 ~,58 N 29.60 1200~ I19q,36 1088,16 11 q5 N 29, 0 E 1,68 75.57 62,19 N 59,q7 I500, 1291.38 1185,18 1~ 0 N S2. 0 E 2.3~ 97,75 82.71 N 52.29 I~00. 1586~76 'i280.56 ...... 17 SO ...... N ~5. 0 E 5.51 ..... 127.78 .... 107.93 N 68,67 1500. lq-81.17 157q-.97 19 15 N 54.. 0 E 1.77 160.74. 155.26 fi 87.10 1600, .......!57q..21 ......... 14"6'8'"~0"~ ......... 2'1--5'0 ............ ~--55-;-'0'-'E. .... ' .... 2';27 ............ 197;-59 165;29 ....N 1700, 1665.56 !559.56 24. 0 ti 55, 0 E 2,4.9 258,06 198,60 N 19 20 OO, 1756,56 .......... 1650,$6 ................... 2q .... 50 ..................... N 36~' O-'E ...... 0,6~ ............. 279,55 ............... 252'15 N ......... 155,-85 00, 18~7.19 17~0,99 25 0 N 55. 0 E 0.65 521,79 266.77 N 180,07 00, 1957,65 18S1,4.5 25 15 N 5~. 0 E 0.~9 564.,4.q 502,1~ N 205,92 21 22 25 00, 2028,07 1921,87 25 16 00. 2116.53 2012,13 25 30 00. ........... 2208 ,'40 .......... 2 iO 2' ~"20 25 -4.5 N 54.: 0 E 0.01 4.07.11 N ;54. 0 E 0.2,5 450.!5 N 5,4.~-'0--E .............. 0 ~2~ ............... 557.52 N 227.79 575,21 N 251.87 'q'09'25 .... N .............. 276."16 245 250 O. 2298.65 2192.q5 25 30 O. 23q. 3.78 ..... 2257.58 2~-'5I' O. 2389,30 2283.10 24. 26 N 55. 0 E O.g9 556.65 N .... 55;--0 .... E .......... 0',-"05 ................ 558'717 N 51, 0 E ~,01 578~80 '~4.4.9 N 300.85 'q"g 2'T'I'q:-'N ...... 313', 2 ~ ~79,87 N ~29.86 D(~LLY ,,. ¢'...,, _ ' i',C:~,;<T!.',Uh. ?,I\,'ER _ DECE[i[~ER 5, 1976 SU[;VE,v DATf VERT'ZCAL 3LCTIO[~ C;' '" "" '-" Or,r'UTED ALc.,G SPERRY-SUN WELL SURVEYING COMPANY SU5-!6!56 RECORD OF SURVEY ....... TRUE .................................. INCLINATION .... DIRECTION. DOG-LEG .......................................... RECTANGULAR' MEARURED VERTICAL SUB-SEA SEV_~RITY VERTICAL COORDINATES DEPTH DEPTH DEPTH DES MIN DES MIN DEB/lO0 SECTION 2600. 2~80.19 2573.99 2q 39 N 22. 0 E 5.7q 619,q0 5!8.5~ N ~ S ~ · 2700. 2008 91 246~.71 27 28 N 21 0 E 2,85 664.11 561.60 N 2800.'~ 2654.86 .........2548,66 ......... 30--q5 .......... N'-2'f'~'-O' E ......... ~'.28 .................. 713.67 ........ 609,~5'N '" 556.01 57~.5~ 2900, 3000, 3100, 1738.34. 2632.1 . ss 2905.77 2797,57 5k 55 N 21. O'E 2.65 767.03 660 N-2i-~'-O--~ ...... 0-'~-~5 .............. 82~.00 712 N 21. 0 E 0.71 875.97 765 .72 N 59q,06 E .70'--N .......... ~iq.02 .65 N q-sq-.3q. £ ,52O 55O 5qO 55O 56O '570 O, .... E986~-28 ....... 2880'~08 .......... 5~ .... 2~ .................. N .... 21~ ..... 0 .... E ........ 0,'15 ........... 930';75 ................ 818-;59-N ........... gSg.59 E O. 5068.82 2962.62 5~ 22 N 21. 0 E 0.05 985.~5 871.09 N ~7t+.82 E O. ~151.q8 5045.28 54 15 N 21. 0 E 0,11 1040,00 923.65 N 494,99 E O. 5255.98 3127.78 3q 25 N 22. 0 E 0.58 1095.0~ 976.0~ N 516.16 E O, ~1~o25 ~210.0~ 5q ~0 N 22. 0 E 0.25 1150,59 1028,78 N 5~7.%7 E O. - - 5397.69 ........ 3291'-.~9 ........ 35-'27 ................. N 22;' O'E ......... 0.78 ..... 1206.85 ...........1082.55 N ........559.19 E 8800. 3900. ~000, ~79.q9 557~.29 55 7 N 22. 0 E 0.S$ 3560.58 ....... ,g5q.'58 ............ 55-"'~9'-''~ ........ N'-22; ...... 0 E ............ 0.70 56~1.82 ;55:55,62 ;55 ~0 'N 21. 0 E 0.60 1262.85 1155.89 N 580.7~ E · 1519,81 ........ 1190-'15'-'N ........... ~" 602~'66 ~ 1376.55 12~[58 N 625.56t qt~O0. 5966,65 5860,~5 ;55 ~9 N 21, 0 E 0,01 ~500. r4047.7~t ;59~.5~ 55 ~9 N 22. 0 E 0.60 ~600. ........... ~1'2'8";'8~ 4022.61 55--50 N--22-,--O-E 1602.58 lq62.q'9 N 707.21 165.9,55 i516.75 N 729.15 1716'~-56- .... -~'57!";'0'3-'N ....... 751.06 7oo. t 2o9. g 1o5.29 56 13 N 22. 0 E 0.38 .. 56 ~ N 22. 0 E 0.15 ~6 5 N 22, 0 E 0,01 177~.06 1625.81 N 775.19 ~, ~$51"~5'6 ..... ~6'~*0.~0 N 795°25 ~' 1888.70 1735.0i N 817.51 C. ..... -,,D, mR 3, 1976 VERTICAL SECTZOW COMPUTED S L!!,', VE' Y DATE A LOS~'& CLnSUT~r SPERRY-SUN WELL SURVEYING CO''''~',~F,r¢.~Y SU3-16!36 RECORD OF SURVEY '- TRUE ............................... INCLINATION DIRECTION APURED VERTICAL SUG-SEA DEPTH DEPTH DEPTtt DEG MIN DEG DOG-LEG RECTAiIGLILAR SEVERITY VERTICAL COORDINATES DEG/IOO SECTION 5000. 5i00. 5200. 4451.91 43q5.7! 36 8 N 23, 0 E 0,59 N532.48 N426.28 56 19 N 23. 0 E 0.18 ~612.73 ..... q506,53 .............. 36-38 .............. Iq 23. 0 E 0o31 1946,53 1789.29 N 8q0.35 200~.21 18~3.80 N 863.~9 2062,52 .......... 1598,73 N 888,8~. 53 5q 55 5GO 57O 580 O0 ' ....... ~773',"96 ~667.~76 56 ..... '~ , q'85~,32 ~7~8,12 36 32 ,- ........... 9 s a ¢ .... ,-I. 82-8 ;- . 5013.08 ~906,88 58 6 N 22. 0 E 0.6! 2Z20.q2 1955.88 N 909 N ..... 22'~ ...... 0 ~ ...... 0,~5 ........... 2177.7i .............. aO'OS'N~-N ......... 931 N 23. 0 E 0.76 2255.89 2063.2~ N N 2~. 0 E 0.65 229~6~ ........... 2~-i7';"96 ..... N ............... 978 N 28. 0 E 2.75 2355.86 2172.44 N 1007 5093,16 ~986.96 36 g8 N 32, 0 E 2.75 2~15.66 2223,2N N 1039 .09 £ .13 E °39 E . . . .76 E ,73 E .~+7 E _ . 590 600 610 . O, O, 5175,05 5068.85 ~5 1 5257.32 5151.12 5q 39 5339.81 ...... 5233.61 .............. 3N 25 N 39. 0 E ~.~7 2~72.92 2267.8~ N 1075.58 E N 39. 0 E 0.56 2529.65 2312.02 N 1111.56 E N 40. 0 E 0,61 2585.98 .... 2355.32 N ' 1147.69 E 62 00, 00. 00, b~21,53 5315.$5 35 12 N ~0, 0 E 0,78 26q5.42 2399.~8 N 118~,7~ E 5502.9~ ........ 5396,-7~+ ............. 35-30 .................... ~N-~O"---"O ...... E ............... 0.30 ............. 2701-',29 .........2qq3',9~-N .......... 1222.07 F b58~,50 5~78,30 35 21 N ~0. 0 E 0.15 2758.95 2~88.28 N !259,2~ 65 66 -67 00, ..... b¢66,33 ............ 5560"'~I3 .................... $5' 5 .......................... N 00, 57~8.35 56~2,15 5~ 5~ N 00, 5830.10 5723.90 55 10 N ql. '-O'-E .... 0.63 " 2816.!~ ........ 2551'66 N ...... 1296.97 E N1. 0 E 0.18 2875,06 257~.8~ N 133~,51 E ~1, 0 E 0,26 2930,56 2618.~I N 1572.29 E 6800. 5911,75 5805,55 35 17 5 6900, 99Oo~1 5887,21 7000-~, ....... 607~-,'92 .......5968.72 N ~i. 0 E 0.1! 2987,85 2661.90 N 1~10.19 E N ~1. 0 E O.ON 30¢+5.23 2705,~ N iN~8.O~ E 7100, 6156.18 60q9.98 55 59 7200 , ......... 62:37'~4. 2, ....... 6'! ,3 ~--~'-2~ 55-q'0 7300, 6519.5~ 621~,Iq 55 0 N q2. 0 E 0.6~ " 5!60.7q 2792.q8 N 1525.0q [. N-~2;--O-E ......... d.-O1. 3218';6~~-2855';8l-N .......... 156q,05 E N 42, 0 E 0,66 3275.60 2878.q3 N 1602.~5 E VERTICAL SEC'iIOlJ COZHL;TEb ALC,~:G CLOSUF..£ SPERRY-SU~'',, WELL SURVEYING COi'iPANY SU5-16!36 TR MEARURED VERT DEPTH DE RECORD OF SURVEY UE .......................... IFJcLINATION .... DIRECTION' DOG-LEG ......................................... RECTAhjGU["LR .............. ICAL SUB-SEA SEVERITY VERTICAL COORDINATES PTH DEp_T.._H_ ....... _D_EG MIN __DEG MIN . DEG_/~_0?_ ....... _~ECTION 7qO0. 7500. 7~00. 6555 .22 6295.02 35 2 N ~$. 0 E O. .qO ~377o20 .5~ q.~ N ~:5. 0 E' O. .96 ......6q59,7& .......... 5q 21 ................ iV-q3~'--O-E .........O' 57 3332.q8 2920.41 N 1641.58 E 30 3388.93 2962.08 N 1680.44 E .38 ............ 3q-q-q'.8q' .......... S003'~;35'~N ........ !718.9i _ 7700 7800 7900 6648.87 65~2.67 ~ 0 6813.77 6707.57 3q' 30 N qq. 0 E N--q q'~"-O E N qq. 0 E 0.66 500oll 30q. .57 N 1-757.77 0", ............ 3555.97 ........... ..... 1797 .-03 0.08 i24. 8 N 1 6.28 8000 8100 820O . .......... 689~,29 -'-6790-~'09 34'--2~ N ¢5~---'0---E -'-0'".-57 ............. 3667:62 ............... 316-~-~'93 .... N- ........ 1876,33 E .... , 6978,37 6872.17 3q 50 N qS. 0 E O.q3 3723.91 5205.31 N 1916.71 E . 7060.76 695q,56 5q 5! N q6, 0 E 0.65 5779,58 52qq.68 N 1957.q8 E 8300 8500 . 71q3.1q 7036.9q 3q 32 N q6. 0 E 0.01 3835.27 528q.06 N 1998.25 E . 7225.65 7119.q5 3q 2q N q6. 0 E 0.13 3890,77 3323.30 N 2038.89 E . 7308.21 7202.01 ............. 5q 21 ................ N ~6'. O-E .... 0.04 ...... 5946.20'' 3562.50 N'- 2079.q8 E 8600 _. 8700 8800 N q6. 0 E O.Oa ~00S.59 3q01.66 N 2120.04 E N 46. 0 E 0.75 ~055-~90 5'~'0'~-07'-N- - -2!59';81"' E N q6, 0 E 0,6~ q111.12 5q79.11 N 2200,2( s 890O ~000 9100 51 ............. 4!65,60 ............... 5517.64"N ........... 2240-'1q E 57 422.0.09 3555,60 N 2280.8q E 18 q27q,83 3593.73 N 2321.7q E ~3200 9300 _ . 9~.~ 00 9500 9800 9700 · 7889.27 7783.07 3:5 qO . 797S.Si 7867.1~ aa ~9 . ........... soss-~'78 ..... 7,~-3-0-;58 ~s"-25 . ....... 82'2S'; 70 .....8 i'i'7',-50 ......... 5 . 8307.29 8201.09 5~ 17 N q7. 0 E 0.3;5 ~$29,10 3631,54 N 2362.28 N qT, 0 E O.Sq 4.382.16 .3668.50 N 2q01.92 N q7"~--O--E ........... 0 ;-&O ............ 'q~$6"~'"0 7 .... 370-6"~"~'6-'N .......... 2qq2 .'19 i'; i-'~ 6 L 6 SURVEY DATE A L'Oi,~ G CLOSUiiE SPEKRY-SUN WELL SURVEYING COMPANY SU5-16155 M£A[~UR D~'PT,_ 9 9 10 RECORD OF SURVEY 90 O0 IRUE I,,,CLiNAT'ION DIRECTION DOG-EEG RECTAI'jGULAR ED VERTICAL SUB-SEA SEVERIIY VERTICAL COORDINATES H DEPTH DEPTH DEG MIN OEG MIN DEG/!00 SECTION , 5391,16 828q,96 ~3 0 N ~9, 0 E 0.61 q650,33 ~853.6~ N 260~.6N E , 0~7~,92 8368.72 33 7 N ~8, 0 E 0,55 4705~6! 3890.20 N 26q5.2~' E o ....6558.8~ ..... 8~52.66 ............32 .... 5'5 ................ N'-~8. 0'" E .........0.19 ...... ~75'6.61 ..... $926,56 N -' 26&5.6= E 010 020 O3O Oq-O 050 O55 o. ..... ~s98.5'0 ........ 8792-;'i'0 .......... '3i .... i'8 ............ N'"-'~'9.--'O .... E- ....... 0"67 ................ ~9S~-,'89 ............. ~06~-'~68 '-N ......... 28~5.9z'- E O. 898~.88 8877.68 51 9 N 50. 0 E 0.55 50~2.91 q097.95 N 2885.55 E O. ~026.79 8920.59 50 5~ N 51. 0 E 1.l~ 5036.62 ~1i~.09 N 2905.~9 E , THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE TANGENTIAL OR CHORD METHOD HORIZONTAL DISPLACEMENT = 5036,62 FEET AT NORTH 35 BEG, 15 MIN, EAST(TRUE) Union Oil and Gas Di', ;n' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union December 15, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE' TBUS D-31RD Dear Mr. Hamilton' Enclosed for your files are two (2) copies of the Monthly Report of Drilling & Workover Operations for the above captioned well. Very truly yours, District Drilling Superintendent jw Encl. cc' Atlantic Richfield Company Marathon Oil Company USGS - Rodney Smith I.'mm No. P-4 RF.V. J~!-70 SUBMIT IN DUPLICATE S~ATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. APl NUMERICAL CODE 50-133-20215-01 760'FSL, 1213'FWL, Sec. 6, T8N, R13W, SM Leg A-l, NE, Dolly Varden Platform LEASE DESIGNATION AND SERIAL NO. ADL - 18729 I. 7. IF INDIAN'ALOTTEE OR TRIBE NAME O~L r~],. GAS [--] Water Injection WELL WELL OTHER 2. NAME OF OPERAI'OR 8, UNIT FARM OR LEASE NAME Union 0il Company of California* Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 6247, Anchorage, AK 99510 D-31RD 4. L<~TION OF WELL lO. FmLD AND mOL. OR W~L<~T McArthur River Field , 11. $~. T. R. M. (BOSOM IIOLE OBJE~IVE) Sec. 6, TS~, R13~, S~ 12. PERMIT NO. 76-74 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTtiER SIGNIFICANT CHANGES IN HOLE CONDITIONS. TRADING BAY uNIT WELL D-31RD - WATER INJECTOR - NOVEMBER, 1976 TD as of 11-30-76 - 10,630'MD 11-01-76 - 11-26-76 11-27-76 - 11-30-76 Drilled and surveyed 12¼" directional hole from 5643' to 10,593'. Ran SP-DIL, BHC-Sonic, & GR-Density logs. Resumed drilling to TD at 10,630'. Ran 256 jts of 9-5/8" casing and landed at 10,630'. Stage collar at 7077', float collar at 10,584', and float shoe at 10,630'. Cemented with 2500. sacks of Class G c~ment. Flanged up BOPE and tested--OK. RIH to 7030' and tested casing--OK. * Marathon Oil Company - Sub-Operator SIGN~ -~'-//( -(g'2t/&¢:.¢ ,,.dc. t.// TITLE D' St. Drlg. Supt. OATE__ ' .. /,.",l.' 'R_ l]~l londor i I ,, NOT~epo~ on this form is r~uired for each calendar month, re~ardlem of the ~atus of o~ratiom, and mu~ be fil~ in duplicate with. the oil ~nd ~ conse~ation committm by the 15th of th~ mcc~ino month, unim othe~ise dirmt~. ~o.~ ~o. r-~ STATE OF ALASKA ~. ~- I-?O OIL AND GAS CONSERVATION COMMITTEE SUBMIT l]q EITu_"PLICAT'E JVIONTNLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L~,L,. ~ OA,~ [~ OT,~' Water Injection 2. NANIE OF OPI~TOR Union 0il Compan7 of California~ ~ ADDRESS OF OP~ P. O. Box 6247, Anchorag.e, , LOCAnON Or wmm 760'FSL, 1213'FWL, Sec. 6, Leg A-l, Nh, Dolly Varden AK 99 510 T8N, R13W, SM Platform 50-133-20215-01 LEASE DESIGNATION A.N-D 5EEIAL NO ADL-18729 7 IF IND1A]q', A!-,O'~"T'EE OR TRIBE NA~E L.~IT FAP,~I OR LEASE N,~dE Trading B_a.y Unit ~VELL NO No. D- 31RD 10 FIF. LD AND PC~L. OH \VILDCAT ..... __McArthur River Field Sec. 6, TSN, R13W, SM 12 PERMIT 1~'0 76-74 13. REPORT TOTAL DEPTH AT END (bF MONTH, Ct:[/kNGIkS IN HOLE SIZE. CASING AN~D CEMENTING JO~S INCLUDING DEPTH SET A~ VOL~ES USED. PERORATIONS. ~TS ~ RESULTS FISHING JO~ JI~K LN HOLE AND SIDE-~.ACKED HOLE AND ~Y O~{ER SIGNIFIC~T C~NG~$ ~ HO~ CO~ITIONS TRADING BAY UNIT WELL D-31RD - WATER INJECTOR - OCTOBER, 1976 TD as of 10-31-76 - 5643'MD RU ove Instal parte engag btm. csg & Cut c assy to 56 r D-31 on 10-17-76. Killed well, set BPV, & removed Xmas tree. led & tested BOPE. Worked pkr free & POH w/ 35" tbg. Tbg d in hole @ btm of circ sly. RIH w/ fishing tools on 5" DP & ed fish @ 9521'. Recovered all of fish. Spotted cmt plug on · Pressured up on plug--held OK. Tagged cmt @ 9513'. Pulled worked slips out. Ran free point indicator--pipe free @ 2630. sg @ 2630 & pulled out. Laid 219-sk cmt plug. RIH w/ drlg & drld to KOP @ 2507'. Drld & surveyed 12¼" hole from 2507' 43' . A ~ Marathon Oil Company - Sub-Operator , , ,~ ]. n ,;~ ' - hereby certiiy//that/~ie ~goi~,is t~e ~ ~~/_3:,(~ZZ,~'~~ =~ Dist. Drlg. Supt. SlG~ //J . K~" --~ ~e~'..~,~,1 , ~ ,.. N~TE--R~port on this form is r~quired for ~ach calendar ~nth~ re~ordl~ss of lbo Itotu~ of op,rotion$, ond must ~ filed tn dupllc~te with the oil .nd ~os conIIrvotJon comml~/e bythe I~ of th~ ~ucc~ding month,unl,~ ~th,rwis~ d~r~ci~d. October 11, t9'/'6 Trading Bay Unit ~. O-31 RD Union Oil Company of California State Permit J. R. Ca l lender Oistrict Drt 11 lng E~lneer Union. Ol I Coapan¥ of Cal lfornla P. O. Box 62Zt7 Anchorage, Alaska ~510 Dear Sir: Enclosed is the approved appiication for permit to drlll the above referenced ~tI at a. location in Sectl~ 6, Township .SN, Range 13~, S. H. ~ll s~les, core ~nfps and a ~dd log are not required. A dlrectlonal survey Is required. Fany rivers In Alaska and their drainage systems have been classified as i~rtant for the s.pawnl~ or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Admtnlstratlve Code). Prior to c~nctng operations ~ may be contacted by the Habitat Coordlnator's office, I)epart- ~nt of Fish and Game. Pollution of am waters of the State ts prohibited by AS q6, Chapter 03, Article 7 and the regulationS'promulgated thereunder {Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~/ater Pollution Control Act~ as ~nded.. Prior to commencing operations you may be contacted by a representative of the Department of Envlronmental Conservation. Pursuant to AS 38.~0, Local Hire Under State Leases, the Alaska Department of Labor is being ~tlfl~ of the issuance of this permit to drill. To aid us in schedu!lng field work, we~ould appreciate your notifying this officewlthin ~8 hours after the~ll is spudded. We would also like to be notified so that a representative of the Otvlsion may be present to witness testing of b1~t preventerequipment before surface casing shoe is drllled. J. R. Callender October 1I, I~176 In the event of suspension or ab~nt ptease give this off!ce ~quate advance not l f I cation so that we may have a wit~Ss present. Very truly yours, Hoyle H. Hamilton ., Chairman Alaska 011 and Gas Conservation Committee Enc I osu re cc ,' Department of Fish and Game, Habitat Sectlo~ w/o ~1. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor La~ Con, l lance Olvlslon w/o er, cl. Porto IO-- 4OI , B-L~V- I -- I-- 71 TYPE 01~ WOIIIK STATE OF ALASKA SUBMIT IN TRIPLIc..'~ (Other instructions on reverse side} OIL AND GAS CONSERVATION ,COMMITTEF PERMIT TO DRILL OR DEEP~I .... ' ....... DRILL b, TYPI~ OF WELL O,L WELL WELL NAME OF Union Oil Company of California* APl No. 50-133-20215-01 . '- ', ,- , , , , , :~ --7 L ~ ,. LEASE DESIGNATION AN-D SEii~IAL NO, ADL-18729 MUI.TIPI,g [] ZONE 3.ADDR~ O'F OPFA:L~TOR Post Office Box 6247, Anchorage, AK 99510 4. LOCATION OF WELL Ats,,rface 760'FSL, 1213'FWL, Sec. 6, T8N, RI3W, SM, At proposed prod. zon, Leg A-l, NE, Dolly Varden Platform G-1 Sand Top: 1200'FEL:. 600'.FNL, S,ec.. 6,. TSN.,. ,R13W, SM 13. DISTANCE IN MILES AND DIRECTION F~OM NEAREST TOWN OR 'POST OFFICE* A~pproximately 21 miles NW of Kenai~ AK l~. ,GNP ~NrOR,~IATION: Uni ted Pacific Insurance Company Trading Bay. Unit D-31 RD 10. FIELD AND POOL. O1~ WILDCAT McArthur River Field ~1. SEC.. T.. R.. M.. (BOTTO.~! HOLE OBJECTIVE) Sec. 6, TSN, R13W, SM TYPE Sta tewi de s.,ety ~nd/or ~o. 8-55502 D.ISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, ~r. (AI-~o to nearest drig. unit. i£ any) 4123' from West Lease Li ne 18. DISTANCE FROM PROPOSED LOCATION" TO NEARESI' WELL DRILLING. COMPLETED. OR APPLIED FOR, FT. 2377' f..rom.Well D=32 ........ 2'1. ELEVATIONS ~Show whether DF. RT. CH, etc.~ KB Elevations: 106.2' above MSL NO. OF ACRES IN LEASE '3085 acres Va0vos~o 9' 190'TVD IO~600'MD ~o~t $100,000 17. NO. ACRES ASSIGNED TO THiS WELL. 80 acres (water injection) 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX, DATE WORK WILL START* 10-15-76 23. PROPOSED CASING AND CEMENTING PROGRA~NI SIZE OF HOLE SIZE OF CASING WEIGHT pER FOOT GRADE [ S=riq-ING DEP~ quantity of cement 3~" ca.S. inl~ is set at 355' 20" casin~ is set at 718' !3-3/8" c~sing is set at 2492' .......... 9-5/8" casing presenLtlv sea. at 10,,'1!'8'' ..~ _ 12¼" 9~5/8'.'. ~. 47// N~80 ~. 10,600' ..... Approxi. mgte.ly. 3200 sx. P-110 Plug the existing wellbore and G Zone perforations from 9619' - 9769'. Cut and pull the 9-5/8" casing from surface to below the 13-3/8" casing shoe ~ 2492'. Drill a 12¼" directional hole to a new location with the G-1 sand top as the target at 1200'FEL, 600' FNL, Sec. 6, T8N, R13W, SM. Proposed TD is at IO,600'MD. The 9-5/8" casing will be run to TD and cemented. The well will 'be completed with a permanent packer and 3½" tubing as a G Zone injector in sands G-2, G-3, G-4 and possibly G-5. IN ABO~ SPA~ D~BE ~OPOS~ PR~.~: I~ ~I Is 1o dee~n 'give ~ on present ~u~tve new prffdu~ve zone. 1~ ~vo~l ls ~ flrlll or O~n d~e~[on&lly, give ~e~ent ~' on s~bsuffa~ ~t~ 're.teal dept~. Glv~-bi6~b[ ~re~eoter' p~g~am. ~4 I here-~71' . ~,~,,~"~;.~,y ,er*' t at the ~egoing l~e~o~e~ ~,, ~ Sep,tember 20, 1976 Dis't SIGN ~_ . . TI'I~ - - , (This space ~or S~te oH~ce u~) CONDI~ONS OF ~PROV~, IF A~: S~M~D Y~ A~CO~Z~O crees n~u~ Il'. mUDS y~LO~ ~o ~ m~o~ su~v~ ~~ *.-.L ~c~ con~ ~ ~ ~'o 50-133-20215-01 P~.~T .~o.- 76.: 74 .,_ ,.~ov,~ ~^~ '~ '.f ' ' ' *S~ I.~udio., O. Reven~.Side *Marathon Oil Company - Sub-Operator October ll., 1976 October ~11, 1976 - DOLLY VARDEH pL~ FORI~ --. ~Id,/c, .,x 5,GOO (l-I>,¢t,-i t -'I Colior !-.5 ~/~ .Su~fo, c.e 3'3" .... ,, ,. ,,, H (Blihd Rc~m0 !1 -- ' ',;' ,- .~ ~~:: .G 1--¢j~ Zf~. ,~, ~/,2'%.,~" .~¢--~L~'E,°O~;' '.'ti;'/ ' ........ ~'-. .... %~-'-" '."'. ~ ...... ....... . .. : . ' - ~ ~CIW SVzi'n~-bolt Clomp ' - Diea~am~ 2 -I~S/¢"~ 5,000 ' Fe - o 1'~ · , OJ . Riscl-a ~OP ~tacl< FoF t_O ~ , ' . .. . .!a-- ] [ __~' 2Ft-. I I ' 0 0 0 ~ " Fl om~ e.<[ Outlets ~ ~lvcs .o. o o ~27 0 o ~ ~-2~ 0-31 b-2o ~ b'3 · 0 a.. o o .6'~ 0 ~-?~ . 0 .. o TRADI BAY .. STRUCTURE CONTOUR MAP ' ! TO~ LOW£~ G-I $^~D -. ! CHECK LIST FOR NEW WELL PERI~,ITS 1. Is the permit fee attached . Company ~/Y2 /~)~ Yes Ho Remarks Lease & Well No. ~T,/~',~, 2. Is well to be located ina defined pool ......... 3. Is a registered survey plat attached 4. Is well located proper distance from property line ....... 5. Is well located proper distance from other wells . 6. ts sufficient undedicated acreage available in this pool . . 7. Is well to be deviated ........ ,~. Is operator the only affected party 9. Can permit be approved before ten-day wait . iO. Does operator have a bond in force . . ll. Is a conservation order needed .............. '2. Is administrative approval needed · ' . . 13. Is conductor string provided ............. ~, ia. Is enough cement used to circulate on conductor and surface . i5. Will cement-tie in surface and' intermediate or production strings 16. Will cement cover all known productive horizons ....... A??!? 17. Will surface Casing protect fresh water zones 18. Will all casing Qive adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rati.ng '. Additional Requirements' Approval Recommended' Geol q_gy Enaineerina,' JAL' k C S,,,?15;¢~::' ..... dCM Revised 1/15/75
