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202-019
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 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,042 N/A Casing Collapse Structural Conductor Surface 1,540psi Production 4,760psi Liner 5,410psi Liner 6,350psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 228A McArthur River Hemlock Oil Same 9,797 15,042 9,797 2519 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,780psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 202-019 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20105-02-00 Hilcorp Alaska, LLC Trading Bay ST TBU A-15RD2 Length Size Proposed Pools: L-80 TVD Burst 9,194 7,240psi MD 6,870psi 3,090psi1,054 6,848 1,07313-3/8" 9-5/8"8,157 1,073 8,157 See schematic 8,376 4-1/2" See schematic 9,7867" Other: Install ESP 5/27/2025 14,9392,742 3-1/2" 9,805 See schematic See schematic 12,380 Perforation Depth MD (ft): m n P s 2 6 5 6 t T N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Taylor Wellman for Dan Marlow By Gavin Gluyas at 12:51 pm, May 27, 2025 325-327 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.05.27 12:40:13 - 08'00' Taylor Wellman (2143) 27MAY2025 A.Dewhurst 27MAY25 Mel G. Rixse - Senior Petroleum Engineer YES MGR27MAY2025 * BOPE test to 3000 psi. Annular to 2500 psi. 10-404 DSR-6/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.05 08:01:11 -08'00'06/05/25 RBDMS JSB 060525 Recomplete to Hemlock Well: TBU A-15RD2 Revision: Re-run ESP 5/27/25 Sundry 325-062 – Change to approved program Well Name:Trading Bay State A-15RD2 API Number:50-733-20105-02-00 Current Status:Offline ESP Oil Producer Leg:Monopod Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:202-019 First Call Engineer:Eric Dickerman (907) 564-4061 Second Call Engineer:Casey Morse (907) 777-8322 Max. Expected BHP (Hemlock):3,304 psi at 7,854’ tvd (8.1 ppg EMW) – From A-15RD2 ESP gauge BHP data 5/24/2025 Max. Potential Surface Pressure:2,519 psi – (Hemlock BHP with 0.1 psi/ft gas gradient to surface) Field/Pool:McArthur River, Hemlock Oil Proposed Production Interval:Hemlock, 12,410’ – 14,939’ md Brief Well Summary Monopod A-15RD was drilled Feb 2002 targeting the Hemlock formation in the North Trading Bay Unit. The A- 15RD2 sidetrack deepened the well and added two laterals L1 and L2. The well was converted from gas lift to an ESP in 2014 and a 4-1/2” scab liner was installed across holes in the 7” liner. The ESP failed in 2015, and the supporting injector A-29RD went Not Operable due to TxIA communication. Due to the failed ESP and lack of injection, A-15RD2 was recompleted uphole to the Middle Kenai A sands. Since that time the Hemlock has had minimal offtake in the area and reservoir pressure has declined only slightly possibly indicating aquifer influx. The well is currently a marginal producer at 10 bopd. This in conjunction with adequate reservoir pressure without waterflood injection leads to this project to re-access Hemlock production. Objective: Recomplete the well from a gas lifted Kenai Sands producer to a Hemlock ESP producer. Install a scab liner to shut off Kenai Sands.Complete. Pull and Replace ESP. Recomplete to Hemlock Well: TBU A-15RD2 Revision: Re-run ESP 5/27/25 Sundry 325-062 – Change to approved program Notes on wellbore condition: - Last casing test: Tubing by 9-5/8” annulus tested to 1,550 psi after setting production packer at 4,054’. May 11, 2015. - No Flow Test: The well would pass No Flow tests when previously completed as a Hemlock ESP producer. Therefore, a production packer and subsurface safety valve are not planned to be installed. Due to recent failed No Flow Test on Steelhead Platform M-32, a SSSV and Packer are planned. -History: o A-15 abandoned Nov – Dec 2001. o A-15RD abandoned Feb 2002. o A-15RD2 completed with L1 and L2 laterals Mar 2002. o Passing No-flow test November 27, 2013. o RWO to convert from gas lift to ESP - Feb 2014. Production liner cleaned out to 14,960’. 4-1/2” scab liner installed over 7” liner where caliper showed 7” damage. 3% KCl working fluid. 3,475 bbl total fluid loss to well. Pressure tested wellbore above 4-1/2” liner top packer to 1,500psi. o Lost injection support April 2015. o RWO to pull ESP, plug back Hemlock, uphole recomplete to Kenai Sands – May 2015. Fished parted tubing and ESP. Hemlock isolated with 9-5/8” CIBP at 6,100’. The 9-5/8” passed 1,500psi pressure test May 7, 2015. FIW working fluid. 1,789 bbl total fluid loss to well before Hemlock isolated. 9-5/8” passed casing test to 1,550 psi after installing gas lift completion May 11, 2015. Recomplete to Hemlock Well: TBU A-15RD2 Revision: Re-run ESP 5/27/25 Sundry 325-062 – Change to approved program RWO Procedure: 1. Skid Monopod Rig 56 in to position over A-15RD2. 2. Circulate well to KWF: a. Work over fluid will be Filtered Inlet Water (8.4 ppg). b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading. c. Total WBV (initial kill) = 435 bbl i. Tubing volume to 3-1/2” tail = 36 bbl ii. 9-5/8” x 3-1/2” to packer = 249 bbl iii. 9-5/8” volume to CIBP at 6,100’ = 150 bbl d. Total WBV (open to Hemlock) = 727 bbl i. 9-5/8” to 8,010’ = 587 bbl ii. 7” from 8,010’ – 9,547’ = 58 bbl iii. 4-1/2” from 9,547’ – 14,939’ = 82 bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached). a. Notify AOGCC 48 hours in advance for witness. b. Test to 250 psi Low / 3,000 psi High / 2,500 psi Annular. c. BOPE will be used as needed to circulate the well. 4. Pull BPV/TWC. 5. Pull hanger to the floor, then lay down 3-1/2” Gas Lifted completion. RU eline for tubing punch and cut as needed. 6. PU work string. 7. Recover 9-5/8” production packer at 4,054’. Utilize BOPE as necessary to circulate any gas present behind the tubing tail. 8. RIH with a 5” kill string to ± 4,100’. 9. Land hanger. 10. Set BPV/TWC. 11. ND BOP. 12. NU dry hole tree. 13. Pull BPV/TWC. 14. Keep the hole full with KWF. Record daily fluid loss to the well and report daily to AOGCC until rig operations are resumed. 15. Bullhead kill if necessary. 16. Set BPV/TWC, ND tree, NU Hilcorp BOP stack. a. Notify AOGCC 48 hours in advance for witness. b. Test to 250 psi Low / 3,000 psi High / 2,500 psi Annular. c. BOPE will be used as needed to circulate the well. 17. Pull hanger to the floor, circulate surface to surface, then lay down 5” drillstring. 18. Continue fishing operations. 19. Recover CIBP milled up from 6,100’. 20. Dress off 7” liner top. 21. Set 7” retrievable bridge plug at ± 8,150’ (below the current 7” liner top). 22. RIH with 7” scab liner as follows: a. Seal assembly – stung in to top of 7” liner at 8,010’. b. 7”, 26#, L-80 scab liner. Recomplete to Hemlock Well: TBU A-15RD2 Revision: Re-run ESP 5/27/25 Sundry 325-062 – Change to approved program c. 9-5/8” x 7” liner top packer assembly. 23. Sting seal assembly in to 7” tie back sleeve. Pressure test the seal assembly to 1,500 psi for 30 charted minutes. 24. Set 7”scab liner isolating the existing Kenai Sands perforations at 4,140’ – 5,100’. Estimated top of new scab liner is ± 4,100’. 25. Pressure test on top of liner top packer to 1,500 psi for 30 charted minutes. 26. Pull the 7” retrievable bride plug. 27. Drift / cleanout the 7” liner interval down to the 4-1/2” liner top at 9,547’. 28. Drift / cleanout the 4-1/2” production interval down to target depth of ± 14,960’. 29. Lay down or rack back workstring. 30. Run new ESP completion with gas lift mandrels. Estimated end of completion ± 9,450’. a. No packer or SSSV are planned due to previous no flow test results. 31. Set BPV/TWC, ND BOP. 32. NU tree and test, pull BPV/TWC. ESP failed to surface fluid, diagnostics on 5/24/25 and 5/25/25 indicate that the ESP motor is functioning but there is an issue between the motor and pump stages 33. Punch tubing as needed. 34. Circulate well to KWF: a. Work over fluid will be Filtered Inlet Water (8.4 ppg). b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading. c. Total WBV (open to Hemlock) = 556 bbl i. 9-5/8” x 3-1/2” to 4,025’ = 247 bbl ii. 7”, 26# x 3-1/2” from 4,025’ to 8,010’ = 105 bbl iii. 7”, 29# x 3-1/2” from 8,010’ to 9,426’ = 36 bbl iv. 7”, 29# from 9,426’ to 9,547’ = 5 bbl v. 4-1/2” from 9,547’ to 14,939’ = 82 bbl vi. 3-1/2” tubing to intake at 9,338’ = 81 bbl 35. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached). d. Notify AOGCC 48 hours in advance for witness. e. Test to 250 psi Low / 3,000 psi High / 2,500 psi Annular. (Provide 48hr AOGCC witness). f. BOPE will be used as needed to circulate the well. g. Top down – annular, VBRs, Blinds, Flow cross. Planning to omit the 7” single gate since we are done with the scab liner. 36. Pull BPV/TWC. 37. Pull 3-1/2” ESP completion. Inspect ESP. 38. Run 3-1/2” ESP completion. MIT-T to 1,500 psi. MIT-IA to 1,500 psi. Both tests for 30 min on chart. 39. Set BPV/TWC, ND BOPs. 40. NU production tree and test, pull BPV/TWC. 41. Test ESP. 42. RDMO RWO crew and equipment. Operations: 43. Schedule and perform SVS and No-Flow Test. Provide 48 hours notice to AOGGC for witness. Recomplete to Hemlock Well: TBU A-15RD2 Revision: Re-run ESP 5/27/25 Sundry 325-062 – Change to approved program Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Proposed Wellhead Diagram 4. BOP Drawing 5. Fluid flow diagram Monopod Platform Well # A-15RD2 Completed: 5/23/2025 Revised by: EPD 05/27/25 As Is CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 13-3/8” 61 K-55 BTC 12.515” 36.9’ 1,073’ 9-5/8” 47 L-80 BTC 8.681” 36.9’ 8,157’ 7” 26 L-80 VamTop 6.276” 4,025’ 7,645’ 7” 26 L-80 BTC 6.276” 7,645’ 7,981’ 7” 29 L-80 KC buttress 6.184” 8,010’ 12,380’ 4-1/2” 12.6 IBT Scab Liner 3.958” 9,547’ 12,203’ 3-1/2” 9.3 L-80 8rd – Scab Liner 2.992” 12,203’ 12,235’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 12,197' 13,198’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 13,198’ 13,329’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 13,329’ 14,235’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 14,235’ 14,939’ 2-7/8” bull nosed hole finder joint on bottom of liner @ 15,010’ TUBING DETAIL 3-1/2” 9.2 L-80 8rd 2.992” Surface 9,194’ JEWELRY DETAIL NO.Depth MD Depth TVD ID OD Item 1 351’ 347’ 2.313” 5.176” SSSV –SLB TRMAXX-5E, X Nipple 2 374’ 370’ 2.992” 8.50” ESP Packer – DL 9-5/8” x 3-1/2”, 20k# shear release 3 2,069’ 2,036’ 2.867” 5.313” GLM – Weatherford SFO-1, 1” pocket, DGLV 4 3,260’ 3,016’ 2.867” 5.313” GLM – Weatherford SFO-1, 1” pocket, DGLV 5 3,904’ 3,522’ 2.867” 5.313” GLM –Weatherford SFO-1, 1” pocket, DGLV 6 4,004’ 3,600’ 6.276” Baker SLZXP Liner Top PKR/HGR 7 7,981’ 6,710’ 6.276” Baker SLZXP Liner Top PRK w/ tie back 8 8,010’ 6,733’ 6.184’ Baker ZXP LTP with 10’ x 7.5” tie back, HMC HGR 9 9,188’ 7,660’ 2.313” 4.52” 3-1/2” X Nipple 10 9,228’ 7,693’ 4.00” Head Bolt On Discharge 9,229’ 7,693’ 4.00” Pump 400, SF3550, 72S, INC, 15, 1:1AR, SBH, 5 stages 9,338’ 7,782’ 4.00” Intake 9,356’ 7,797’ 4.20” Motor 420, EMS2, 200 hp, 1800V, 77A, 24 RTR 9,426’ 7,854’ 4.56” Gauge/Centralizer/Anode/Press & Temp gauge 11 9,547’ 7,950’ 3.958”Baker S-3 Pkr – 5” pin x 4.5’ VAM Top Pin 12 12,197’ 9,740’ 3.958” Top of 4-1/2” liner with ZXP Liner Top Packer w/ 4.000” seal bore from 12,226’-12.241’ 13 12,203’ 9,742’ 2.992” 3-1/2” 80-40 Locator Seal Assy TD = 15,042’ MD 10,023’ TVDSlotted Liner at Near-Horizontal in HB-1&2 4-1/2” L-80, 11.6# tbg with 2-1/2” x 1/8” slots, 16 slots/ft 13,198’-13,330’ (MD)/9,771’-9,776; (TVD) and 14,234’-14,939’ (MD)/9,877’-9,887’ (TVD) rest is blank liner RKB to TBG Hanger = 39.4’ 1 2 9-5/8” at 8,157’ MD 7” liner cemented at 12,380’ MD/ 9787’ TVD, 76 deg hole angle 12-1/4” hole to 8,464’ A-15RD2L2 A-15RD2, 13,620’ MD TD A-15RD2L1 13,730’ MD TDA-15RD2, Start = 12,700’ MD A-15RD2L1, Start = 13,406’ MD 5/03: Perfed liner 12,410’-480’ (MD)/9,793’-9,804’ (TVD) 3 6 7 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status ANZ 13A 4,140’ 4,300’ 3,705’ 3,828’ 160’ Isolated AZN 25A 4,654’ 5,100’ 4,104’ 4,460’ 446’ Isolated Hem 12,410' 12,480' 9,793' 9,804' 70 Open Hem 13,198' 13,330' 9,771' 9,766' 132 Open Hem 14,234' 14,939' 9,887' 10,005' 705 Open 4 5 2.992” ID 3-1/2” joint 8 X9 10 11 12 13 Monopod Platform Well # A-15RD2 Completed: 5/23/2025 Revised by: EPD 05/27/25 Proposed CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 13-3/8” 61 K-55 BTC 12.515” 36.9’ 1,073’ 9-5/8” 47 L-80 BTC 8.681” 36.9’ 8,157’ 7” 26 L-80 VamTop 6.276” 4,025’ 7,645’ 7” 26 L-80 BTC 6.276” 7,645’ 7,981’ 7” 29 L-80 KC buttress 6.184” 8,010’ 12,380’ 4-1/2” 12.6 IBT Scab Liner 3.958” 9,547’ 12,203’ 3-1/2” 9.3 L-80 8rd – Scab Liner 2.992” 12,203’ 12,235’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 12,197' 13,198’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 13,198’ 13,329’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 13,329’ 14,235’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 14,235’ 14,939’ 2-7/8” bull nosed hole finder joint on bottom of liner @ 15,010’ TUBING DETAIL 3-1/2” 9.2 L-80 8rd 2.992” Surface ± 9,200’ JEWELRY DETAIL NO.Depth MD Depth TVD ID OD Item 1 ± 351’ 347’ 2.313” 5.176” SSSV –SLB TRMAXX-5E, X Nipple 2 ± 374’ 370’ 2.992” 8.50” ESP Packer – DL 9-5/8” x 3-1/2”, 20k# shear release 3 ± 2,069’ 2,036’ 2.867” 5.313” GLM – Weatherford SFO-1, 1” pocket, DGLV 4 ± 3,260’ 3,016’ 2.867” 5.313” GLM – Weatherford SFO-1, 1” pocket, DLGV 5 ± 3,904’ 3,522’ 2.867” 5.313” GLM –Weatherford SFO-1, 1” pocket, DGLV 6 4,004’ 3,600’ 6.276” Baker SLZXP Liner Top PKR/HGR 7 7,981’ 6,710’ 6.276” Baker SLZXP Liner Top PRK w/ tie back 8 8,010’ 6,733’ 6.184’ Baker ZXP LTP with 10’ x 7.5” tie back, HMC HGR 9 ± 9,188’ 7,660’ 2.313” 4.52” 3-1/2” X Nipple 10 ± 9,228’ 7,693’ 4.00” Head Bolt On Discharge ± 9,229’ 7,693’ 4.00” Pump ± 9,338’ 7,782’ 4.00” Intake ± 9,356’ 7,797’ 4.20” Motor ± 9,426’ 7,854’ 4.56” Gauge/Centralizer/Anode/Press & Temp gauge 11 9,547’ 7,950’ 3.958”Baker S-3 Pkr – 5” pin x 4.5’ VAM Top Pin 12 12,197’ 9,740’ 3.958” Top of 4-1/2” liner with ZXP Liner Top Packer w/ 4.000” seal bore from 12,226’-12.241’ 13 12,203’ 9,742’ 2.992” 3-1/2” 80-40 Locator Seal Assy TD = 15,042’ MD 10,023’ TVDSlotted Liner at Near-Horizontal in HB-1&2 4-1/2” L-80, 11.6# tbg with 2-1/2” x 1/8” slots, 16 slots/ft 13,198’-13,330’ (MD)/9,771’-9,776; (TVD) and 14,234’-14,939’ (MD)/9,877’-9,887’ (TVD) rest is blank liner RKB to TBG Hanger = 39.4’ 1 2 9-5/8” at 8,157’ MD 7” liner cemented at 12,380’ MD/ 9787’ TVD, 76 deg hole angle 12-1/4” hole to 8,464’ A-15RD2L2 A-15RD2, 13,620’ MD TD A-15RD2L1 13,730’ MD TDA-15RD2, Start = 12,700’ MD A-15RD2L1, Start = 13,406’ MD 5/03: Perfed liner 12,410’-480’ (MD)/9,793’-9,804’ (TVD) 3 6 7 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status ANZ 13A 4,140’ 4,300’ 3,705’ 3,828’ 160’ Isolated AZN 25A 4,654’ 5,100’ 4,104’ 4,460’ 446’ Isolated Hem 12,410' 12,480' 9,793' 9,804' 70 Open Hem 13,198' 13,330' 9,771' 9,766' 132 Open Hem 14,234' 14,939' 9,887' 10,005' 705 Open 4 5 2.992” ID 3-1/2” joint 8 X9 10 11 12 13 Monopod Platform A-15RD2 Proposed 01/27/2025 BHTA, Bowen, 4 1/16 5M FE x 7'’ quick union top Valve, Upper master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, EE trim Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator 13 3/8'’ 9 5/8'’ 4 ½’’ Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2'’ LPO No slips or packoff in head, removed during 2002 redrill Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Casing spool, OCT-C22-BG, 13 5/8 3M X 13 5/8 3M, w/ 2- 2'’ LPO 9 5/8 casing hung off in this spool, C-22 slips Valve, CIW-F, 2'’ LPO 3M, HWO, AA Tubing hanger, CIW-DCB-FBB-ESP, 11 X 4 ½ IBT lift and susp, w/4'’ type H BPV profile, 4- ¼’’ continuous control lines Monopod A-15RD2 13 3/8 X 9 5/8 X 4 ½ X4 control line Monopod Platform 2025 BOP 01/22/2025 Drill deck 1.76' Riser 13 5/8 5M FE X 13 5/8 5M FE 14.20'’ UOCD 1911 13 5/8 5M Shaffer Shaffer SL Mud Cross 13 5/8 5M FE X FE w/ 3 1/8 5M EFO w/ 2 1/16 5M manual and HCR valves for choke and kill lines 3.74' 13 5/8 5M Rig Floor 16'’ Pipe 2 7/8-5.5 Variables Blind 26.25' Bottom of air boot flange 5' below rig floor 2.83' Spool 13 5/8 5M X 11 5M1.00' 14.20' Hilcorp Monopod Rig 56 Flow Diagram LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve MUD PUMP 4.30' PIT SYSTEM CHOKE MANIFOLD Choke Line Panic Line C12 C13 C15 C14 C16 AB C4 C5 C6 C7C2 C10 C9 C11 C8 C3 P HCR1 Open ClosedClosedOpen Open Open OpenAnnular VBR BLIND SucƟon MUD PUMP SHAKERSHAKERKill Line Trip Tank P P C1 C GAS BUSTER HCR2 4” Demco kill line Flow line P P Hilcorp Monopod Rig 56 Flow Diagram Reverse Circulating 4” Demco kill line LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve MUD PUMP 4.30' PIT SYSTEM CHOKE MANIFOLD Choke Line Panic Line C12 C13 C15 C14 C16 AB C4 C5 C6 C7C2 C10 C9 C11 C8 C3 P HCR1 Open ClosedOpenOpen Open Open ClosedAnnular VBR BLIND SucƟon MUD PUMP SHAKERSHAKERKill Line Trip Tank P P C1 C GAS BUSTER HCR2 Flow line P P 4 11 C To Gas Buster White Normally Open 3-6-7-15 Black Normally Closed 1-2-4-5-8-9-10 11-12-13-14-16 From BOP 1413 10 12 3 2 8 1 B 5 6 7 A 9 16 15 D To Panic Line To Sending Unit Monopod Rig 51 Choke Manifold Item 3 & 5 4, 13, 15, 16 1-2, 6-12, 14 A B-C D ĞƐĐƌŝƉƟŽŶ 3 1/8 5M Vetco 2200T Gate Valve 4 1/16 5M Cameron Gate Valve 3 1/8 5M Cameron Gate Valve Swaco 2 9/16 10M Super Choke 3 1/8 5M Cameron H2 Manual Choke 3 1/8 5M Cameron H2 PosiƟve Choke Install 4 1/16 5M API instrument Ňange below panic line w/ ½ npt drain ports Monpopod Valve Alignment –Long Way Valve PosiƟon (O- Open/ C- Closed Monpopod Valve Alignment –Reverse Valve PosiƟon (O- Open/ C-Closed Annular O Annular C VBR O VBR O Blind O Blind O C1 C C1 C C2 C C2 C C3 O C3 O C4 C C4 C C5 C C5 C C6 O C6 O C7 O C7 O C8 C C8 C C9 C C9 C C10 C C10 C C11 C C11 C C12 C C12 C C13 C C13 C C14 C C14 C C15 O C15 O C16 C C16 C HCR1 C HCR1 C Wing1 (W1) O Wing1 (W1) O HCR2 C HCR2 C Wing2 (W2) O Wing2 (W2) O Demco4”KillLine C Demco4”KillLine O Stand Pipe Valve (SP1) O Stand Pipe Valve (SP1) C Cement Line (CL1) C Cement Line (CL1) C Trip Tank 1 (TT1) C Trip Tank 1 (TT1) C Reverse Line (RV1) C Reverse Line (RV1) O Mud Pump 1 (MP1) O Mud Pump 1 (MP1) O Mud Pump 2 (MP2) O Mud Pump 2 (MP2) O Mud Pump 3 (MP3) O Mud Pump 3 (MP3) O Mud Pump 4 (MP4) O Mud Pump 4 (MP4) O Pit Outlet 1 (PO1) O Pit Outlet 1 (PO1) O Pit Outlet 2 (PO2) C Pit Outlet 2 (PO2) C Pit Outlet 3(PO3) C Pit Outlet 3(PO3) C MP3 SP1 PO3PO2 MP4 MP1MP2 MP3MP4MP1MP2 W2 W1 W2 CEMENT LINE W1 TT1 TT1 RV1 RV1 CL1 PO1 PO3PO2PO1 7" Ram 7" Ram CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Eric Dickerman Cc:Regg, James B (OGC); DOA AOGCC Prudhoe Bay Subject:20250515 0925 PTD 202019 - APPROVAL Sundry 325-062, Trading Bay St A-15RD2 - Update and 2-3/8" workstring Date:Thursday, May 15, 2025 9:36:00 AM Eric, Hilcorp is approved to pick up a 2-3/8” work string. Please assure 48 hour notice to AOGCC for opportunity to witness testing of the 2-3/8” fixed ram. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jim Regg, AOGCC Inspectors From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Thursday, May 15, 2025 9:05 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 202019, Sundry 325-062, Trading Bay St A-15RD2 - Update and 2-3/8" workstring Mel, A quick update on progress for the workover on A-15RD2. We installed the 7” scab liner yesterday and performed a passing MIT, so we have the Middle Kenai Pool isolated and should not need to pursue commingling. The next two steps are to finishing cleaning out the 4-1/2” production liner and then run the upper ESP completion. We have a minimum restriction in the 4-1/2” production liner of 2.995” at 12,203’, which does not leave much clearance for 2-7/8” pipe. After discussing with the team, we plan to pick up a 2-3/8” workstring to cleanout the 4-1/2” production liner from 12,203’ to as deep as possible (targeting 14,960’). Just wanted to communicate our plan since the 2-3/8” pipe size was not included in the sundry. Since we are done with the 7” work, we plan to swap the lower single gate from 7” fixed to 2-3/8” fixed rams and will test the lower rams with a 2-3/8” test joint as per the sundry pressures. We will send in a BOP test witness request. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY ST TBU A-15RD2 JBR 07/18/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 Cellar Methane detector failed to sound alarm and had to be calibrated, 4" outside kill valve failed and was rebuilt, HCR Choke failed to hold and was cycled and serviced. Test Results TEST DATA Rig Rep:Tyson RentonOperator:Hilcorp Alaska, LLC Operator Rep:Shane Hauck Rig Owner/Rig No.:Hilcorp 56 PTD#:2020190 DATE:5/6/2025 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopAGE250512084039 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9 MASP: 2545 Sundry No: 325-062 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 16 PNo. Valves 2 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8 X 5 1/2"P #2 Rams 1 Blind P #3 Rams 1 3 1/2"NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"FP Kill Line Valves 2 2 1/16 & 4"FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1400 200 PSI Attained P41 Full Pressure Attained P195 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2375 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P FPMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P10 #2 Rams P8 #3 Rams P9 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P3 HCR Kill P3 9 9 9 9999 9 9 9 9 9 9 9 Cellar Methane detector failed 4" outside kill valve failed HCR Choke failed FP FP FP Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY ST TBU A-15RD2 JBR 04/29/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 2-7/8" and 5" TJ, Choke HCR fail flange on actuator leaked and steam leak, Grease and cycle pass. CMV #10 fail, Replace valve test again pass. I did not stay to witness valve replacement and test. Test was very slow with trouble shooting leaking CMV 10 valve and other operations. Accumulator bottle precharge was 928 psi avg on 16 bottles. Test Results TEST DATA Rig Rep:Shane HauckOperator:Hilcorp Alaska, LLC Operator Rep:Bruce Herbert Rig Owner/Rig No.:Hilcorp 56 PTD#:2020190 DATE:3/22/2025 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopKPS250322105556 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 14 MASP: 2545 Sundry No: 325-062 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 16 FPNo. Valves 2 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8" x 5-1/2 P #2 Rams 1 Blinds P #3 Rams 1 2-7/8" x 5-1/2 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"FP Kill Line Valves 2 3-1/8" & 4" d P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1200 200 PSI Attained P26 Full Pressure Attained P178 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6 @ 2300 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P7 #2 Rams P7 #3 Rams P8 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 9 9 7HVWFKDUWIRU&09DWWDFKHG FP FP Choke HCR fail CMV #10 fail #01&5FTU)JMDPSQ $IPLF.BOJGPME7BMWF3FUFTU 5#4UBUF"3% 15% "0($$*OTQCPQ,14 • STATE OF ALASKA RECEIVED AL .KA OIL AND GAS CONSERVATION COMk SION JUL 2 2 201. REPORT OF SUNDRY WELL OPERATIONS AO � 1.Operations Abandon El Plug Perforations ❑ Fracture Stimulate II Pull Tubing❑ OraT�� ons shutdown ❑ Performed: Suspend ❑ Perforate C7 Other Stimulate ❑ Alter Casinc❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pod❑ Repair Well Cl Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 202-019 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20105-02 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St/A-15RD2 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil 11. Present Well Condition Summary: T<?btnrl442.1 c:‘‘.4(undiJc:mid, O:\ Total Depth measured 15,042 feet Plugs measured 6,100 feet true vertical 9,797 feet Junk measured N/A feet Effective Depth measured 6,100 feet Packer measured 4,054;9,547;12,197 feet true vertical 5,234 feet true vertical 3,638;7,950;9,740 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Intermediate 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Production 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation depth Measured depth See Schematic feet sl p q True Vertical depth See Schematic feet n 1 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 4,083'(MD) 3,661'(TVD) 312'(MD) Packers and SSSV(type,measured and true vertical depth) Packers(x3) See Schematic BOT TE-5 SSSV 312'(TVD) 12.Stimulation or cement squeeze summary: r 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: 157 325 0 560 120 Subsequent to operation: 127 183 0 594 98 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory DevelopmentE Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG LI GINJ❑ 3USP0 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: 315-402 Contact Trudi Hallett Email thallett(c�hilcorp.com Printed Name �/ / ,� Trudi Hallett Title Operations Engineer Signature 9 61.,t - L12C Phone (907)777-8323 Date 7/21/2015 7 -i,, RBDMS JUL 2 4 2015 Form 10-404 Revised 5/2015 ., s r/Z./._. -- Submit Original Only - tit SCHEMATIC Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: 05/12/2015 RKB to TBG Hanger=40' CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM i 13-3/8" 61 K-55 BTC Surf 1073' 9-5/8" 47 L-80 BTC Surf 8157' 7" 29 L-80 KC buttress 8010' 12380' Ili 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' MO 3 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 4 , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' L 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' 6 s TUBING DETAIL 3-1/2" 9.2 L-80 SuperMax Surf 4,083' 7 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' NO. Depth Item 1 312' BOT TE-5 SSSV w/2.812 BX Profile _ 8 2 2,112' GLM MN 3 2,821' GLM 4 4,028' Chem Injection Mandrel L _ 5 4,054' 9-5/8"36-53.50#Hydraulic Isolation Packer 6 4,072'4X Nipple-2.81"Profile WLEG 12-1/4" hole 9-5/8" 7 8 6,100', ' CIBP IBP to 8,464' at 8,157' MD 9 9,547' Bakers-3 Pkr-5' pin x 4.5"VAM Top Pin 10 12,197' Top of 4-1/2"liner with ZXP Liner Top Packer w/ 4.000"seal bore from 12,226'-12,241' 11 12,203' 3-1/2"80-40 Locator Seal Assy 9 Perforation Data Top Btm Btm Suspected Hole in 7" Z � (MD) (MD) Top(ND) (ND) Amt Status csg b/t 10,089't0 AZN 13A 4,140' 4,300' 3,705' 3,828' 160' Open 10,099' AZN 25A 4,654' 5,100' 4,104' 4,460' 446' Open Hem 12,410' 12,480' 9,793' 9,804' 70 Isolated Hem 13,198' 13,330' 9,771' 9,766' 132 Isolated Hem 14,234' 14,939' 9,887' 10,005' 705 Isolated fill io 15 s 1"\ 7" liner cemented at 12,380' MD/9787'ND,76 deg hole angle + 5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'.(........V..7. ...........................i. .......A-15RD2,13,620'MD TD ''.A-15RD2L1 • • -15RD2,Start=12,700.:..MD 13,730'MD TD _._. f I A-15RD2L2 A-15RD2L1,Start=13,406'MD - _. ]. - 1I-.-.".-N Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023'TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 07/21/15 Hilcorp Alaska, LLC H& u'p Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 7/1/2015 7/3/2015 Daily Gpe tIo , 07/01/15-Wednesday ARRIVE AT MONOPOD.SAFETY MEETING.Start rigging up slickline.Finished rigging up.Pick up lubricator,stab on well and P/T 2500 psi. RIH w/30'2.70 dummy gun and 2.75 gauge ring down to 4,400'wlm,POOH.Rig down slickline.R/U E-line. RIG UP E-LINE.PRESSURE TEST TO 2500 PSI.RIH WITH GUN 1 TO 3,875'.STUCK WITH GUN 1 @ 3,875'.BREAK FREE AND POOH.RIG DOWN.SDFN. 07/02/15-Thursday RIG UP SLICKLINE. Stab on well PIT lub 2500 psi,test good.RIH w/full barb spiral scratcher down to 4,100'wlm.Made several passes from 4,100'—3,700'wlm.POOH.M/U 30'2.70 dummy guns and 2.80 gauge ring.Worked tools from 3,700'wlm down to 4,100'wlm. RID slickline.RIG UP E-LINE.PRESSURE TEST TO 2500 PSI. RIH WITH GUN 1 TO 4,300'.RIH WITH GUN 2 TO 4,268.25'.RIH WITH GUN 3 TO 4,236.5'.RIH WITH GUN 4 TO 4,204.75'. 07/03/15-Friday RIH WITH GUN 5 TO 4,173'.RIH WITH GUN 6 TO 4,153'.RIG DOWN. V OF Tyt • G;w\�����j�,sT THE STATE Alaska Oil and Gas '������, of Conservation Commission -,.,_ -_____ - ALAS :A 'Wittx_ 333 West Seventh Avenue �� *h;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 O- ALAS- l''' Fax. 907.276.7542 www aogcc alaska gov Trudi Hallett AWED JuL 0 7 2 010 — 011 Operations Engineer O Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock, Trading Bay, and Undefined Oil Pools, Trading Bay St A-15RD2 Sundry Number: 315-402 Dear Ms. Hallett: 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 dayif the 23rd dayfalls on a holidayor weekend. Sincerely, /))21e--6474--(-- Cathy P. oerster Chair DATED this da of June, 2015 Encl. RECEIVED JUN 2 2 2Ul„ STATE OF ALASKA pj-5 c1Jt9JIS ALASKA OIL AND GAS CONSERVATION COMMISSION *-,- APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate I] Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name 4 Current Wel Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC * Exploratory ❑ Development D• 202-019 • 3.Address. 3800 Centerpoint Dnve,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20105-02 7.If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B • Will planned perforations require a spacing exception? Yes CI No❑ / Trading Bay St/A-15RD2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 - McArthur River Field/Hemlock Oil&Trading Bay Field/Undefined Oil Pools • 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) 15,042 10,023 6,100 5,243 6,100 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Intermediate 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Production 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9 2#/L-80 4,083 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) Hyd.Isolation Packer,Baker S-3 Packer,ZXP Packer &BOT TE-5 SSSV - 4,054'(MD)3,638'(ND)9,547'(MD)7,950'(TVD)12,197'(MD)9,740'(TVD)&312'(MD)/312'(ND) 12 Attachments Description Summary of Proposal 2 13.Well Class after proposed work Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphif] svelopment❑ • Service ❑ 14 Estimated Date for 15.Well Status after proposed work. Commencing Operations: 7/6/2015 OIL 2• WINJ ❑ WDSP❑ Suspended ❑ 16 Verbal Approval Date: GAS 0 WAG ❑ GSTO❑ 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 Trudi Hallett Email thallettphilcorp.com Printed Name Trudi Hallett Title Operations Engineer i Signature YIAACtiPhone (907)777-8323 Date 6/22/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number `5 - , 1 O Plug Integrity ❑ BOP Test CI Mechanical Integrity Test ❑ Location Clearance CI4` Other. Spacing Exception Required? Yes ❑ Nod Subsequent Form Required 1 a 410 L( I APPROVED BY Approved by: am—! �¢� � e�C� COMMISSIONER THE COMMISSION Date: - � ✓/3 IV G/4‘'6 ff--- -z` -f 5— G I N ALQ Form and Form 10-403 Revised 5/2015 Approved application is va id or 1 months from the date of approval. Attach sin Duplicate RBDMS AApliJul_ - 1 2015 Well Work Prognosis Well: A-15RD2 Hile»rp Alaska,LLC Date:06/22/15 Well Name: A-15RD2 API Number: 50- 733-20105-02 Current Status: Gas-Lift Producer Leg: NA Estimated Start Date: July 6, 2015 Rig: NA Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 202-019 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: 1364 psi @ 4,220'TVD (4,800' MD) Based on static BHP reading 06/21/15 Maximum Expected BHP: 1364 psi @ 4,220'TVD (4,800' MD) Based on static BHP reading 06/21/15 Max Allowable Surface Pressure: 1150 psi Gas Lift Pressure Brief Well Summary Well A-15RD2 is a gas-lifted oil producer completed in the Trading Bay Field (Undefined) Oil Pool. This project will add ±160' of the 13A sand in the Trading Bay Field (Undefined) Oil Pool of the Subthrust fault block. Procedure: 1. MIRU E-line unit. 2. Correlate on depth. 3. Add perforations a. ±4,140'—±4,300' (AZN 13A) 4. Rig down E-Line. 5. Return well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic . H SCHEMATIC Monopod Platform Well #A-15RD2 Hilcoru Alaska, LLC Completed: 05/12/2015 RKB to TBG Hanger=40' CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC _ Surf 1073' 1 9-5/8" 47 L-80 BTC _ Surf 8157' 7" 29 L-80 KC buttress 8010' 12380' 2 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' 3 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' L 4 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' ERs 6 TUBING DETAIL 3-1/2" 9.2 L-80 SuperMax Surf 4,083' 7 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' __ a NO. Depth Item 1 312' BOT TE-5 SSSV w/2.812 BX Profile 11111 NIMI 2 2,112' GLM 3 2,821' GLM L , 4 4,028' - Chem Injection Mandrel 5 4,054' 9-5/8"36-53.50#Hydraulic Isolation Packer 9 5/8„ 6 4,072' X Nipple-2.81"Profile w/RHCP Plug 12-1/4" hole 7 4,083' WLEG to 8,464' at 8,157' MD 8 6,100' CIBP 9 9,547' Baker S-3 Pkr-5"pin x 4.5"VAM Top Pin 10 12,197' Top of 4-1/2"liner with ZXP Liner Top Packer w/ 4.000"seal bore from 12,226'-12.241' 11 12,203' 3-1/2"80-40 Locator Seal Assy M � a Suspected Hole in 7" csg b/t 10,089'to 0 10,099' Perforation Data Top Btm Btm Zone (MD) (MD) Top(TVD) (ND) Amt Status AZN 25A 4,654' 5,100' 4,104' 4,460' 446' Open Hem 12,410' 12,480' 9,793' 9,804' 70 Isolated Hem 13,198' 13,330' 9,771' 9,766' 132 Isolated io it -\ Hem 14,234' 14,939' 9,887' 10,005' 705 Isolated 7" liner cemented at 12,380' MD/9787'TVD,76 deg hole angle 1-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) .......A-15RD2,13,620'MD TD A-15RD2L1 -15RD2,Start=12,700'..MD • 13,730'MD TD • ► A-15RD2L2 A-15RD2L1,Start=13,406'MD - I-I. - -I---- -N Slotted Liner at Near-Horizontal in HB-1&2/ TD= 15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 06/10/15 PROPOSED Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: 05/12/2015 RKB to TBG Hanger=40' CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM MI 13-3/8" 61 K-55 BTC Surf 1073' J. 1,1 9-5/8" 47 L-80 BTC Surf 8157' 7" 29 L-80 KC buttress 8010' 12380' Ell 2 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' 3 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' L 4 , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' MED 6 s TUBING DETAIL 3-1/2" 9.2 L-80 SuperMax Surf 4,083' 7 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' NO. Depth Item 1 312' BOT TE-5 SSSV w/2.812 BX Profile III- - 2 2,112' GLM 1 . 3 2,821' GLM 4 4,028' Chem Injection Mandrel G 5 4,054' 9-5/8"36-53.50#Hydraulic Isolation Packer �► 1P 6 4,072' X Nipple-2.81"Profile w/RHCP Plug • 12-1/4" hole 9-5/8 7 4,083' WLEG 8 6,100' CIBP to 8,464' at 8,157' MD 9 9,547' Baker 5-3 Pkr-5"pin x 4.5"VAM Top Pin 10 12,197' Top of 4-1/2"liner with ZXP Liner Top Packer w/ 4.000"seal bore from 12,226'-12,241' 11 . 12,203' 3-1/2"80-40 Locator Seal Assy Perforation Data Top Btm Btm Suspected Hole in 7" Zone (MD) (MD) Top(ND) (ND) Amt Status csg b/t 10,089'to AZN 13A ±4,140' ±4,300' ±3,705' ±3,828' ±160' Future 10,099' AZN 25A 4,654' 5,100' 4,104' 4,460' 446' Open Hem 12,410' 12,480' 9,793' 9,804' 70 Isolated Hem 13,198' 13,330' 9,771' 9,766' 132 Isolated Hem 14,234' 14,939' , 9,887' 10,005' 705 Isolated 10 u 1,\ 7" liner cemented at 12,380' MD/9787'TVD,76 deg hole angle 1-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) ......A- 15RD2,13,620'MD TD A-15RD2L1 -15RD2,Start=12,700'.MD-- 13,730'MD TD • • ► A-15RD2L2 A-15RD2L1,Start=13,406'MD - EI• - }I-.-.-.-N Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 06/22/15 STATE OF ALASKA A .KA OIL AND GAS CONSERVATION COM. .SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pod 0 Repair Well ❑ Re-enter Susp Well❑ Other: Ran Gas Lift Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory ❑ 202-019 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20105-02 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St/A-15RD2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 110.Field/Pool(s): N/A McArthur River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 15,042 feet Plugs measured 6,100 feR E C E I {�`, E D true vertical 10,023 feet Junk measured N/A feet .JUN 1 2 2035 Effective Depth measured 6,100 feet Packer measured 4,054 feet true vertical 5,234 feet true vertical 3,638 feet A`9OGCC Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Intermediate 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Production 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED JUL Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 4,083'(MD) 3,661'(ND) 4,054'(MD) 312'(MD) Packers and SSSV(type,measured and true vertical depth) Liner Top Packer 3,638'(ND) BOT TE-5 SSSV 312'(ND) 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: 267 505 3542 96 146 Subsequent to operation: 155 310 0 552 134 14.Attachments(required per 20 AAC 25.070,25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP0 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: 315-222&315-276 Contact Trudi Hallett Email thallettahilcorq.com Printed Name Trudi Hallett Title Operations Engineer SignatureJ AAJ - Phone (907)777-8323 Date 6/11/2015 '' RBDMS JUN 2 5 2015 r....,,.In AAA oe..:..e.�=P311.1= l'�- ` J/ CI,ti..,:I n.;..:..�l nn.. • III SCHEMATIC Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: 05/12/2015 RKB to TBG Hanger=40' CASING DETAIL SIZE Mr- GRADE CONN TOP BOTTOM 1III 13-3/8" 61 K-55 BTC Surf 1073' 2 9-5/8" 47 L-80 BTC Surf 8157' 3 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' a L 1 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' s Ki 6 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 7 ...... ' Sy` 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' S/ODr""0 TUBING DETAIL -- 31110111 8 3-1/2" 9.2 L-80 SuperMax Surf 4,083' IIIII 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' L , NO. - Depth Item 1 312' BOT TE-5 SSSV w/2.812 BX Profile 9-5/8" 2 2,112' GLM 12-1/4"hole 3 2,821' GLM to 8,464' at 8,157' MD 4 4,028' Chem Injection Mandrel 5 _ 4,054' 9-5/8"Liner Top Packer 6 4,072' X Nipple-2.81"Profile w/RHCP Plug 7 4,083' WLEG 8 6,100' CIBP 9 12,197' Top of 4-1/2"liner with ZXP Liner Top Packer w/ 4.000"seal bore from 12,226'-12.241' Suspected Hole in 7" 10 12,203' 3-1/2"80-40 Locator Seal Assy csg b/t 10,089'to 0 10,099' Perforation Data Top Btm Btm Zone (MD) (MD) Top(ND) (ND) Amt Status AZN 25A 4,654' 5,100' 4,104' 4,460' 446' Open Hem 12,410' 12,480' 9,793' 9,804' 70 Isolated 9 10 Hem 13,198' 13,330' 9,771' 9,766' 132 Isolated '\ Hem 14,234' 14,939' 9,887' 10,005' 705 Isolated 7"liner cemented at 12,380' MD/9787'ND,76 deg hole angle 1-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) '.A-15RD2,13,620'MD TD A-15RD2L1 -15RD2,Start=12,700'..MD" :.13,730'MD TD _._. 11 A-15RD2L2 A-15RD2L1,Start=13,406'MD - 1-I• - •11-•-•-•-1 Slotted Liner at Near-Horizontal in HB-1&2� TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023'TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:1LL 06/10/15 Hilcorp Alaska, LLC Hi! arpAlaska'.LU: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 04/22/15-Wednesday 04/23/15-Thursday Set BPV. Nipple down 4" tree.Had to remove in sections.Clean up and dress top of hanger.MU blanking sub to tubing hanger.MU and land test joint and mark Blanking sub RK B on test joint.Lay down test joint. Rig up and land drilling riser.Removed 3'spool from top of riser due to height issue.Land and NU BOP Stack and associated equipment.Start putting hatches on the Accumulator tank.tie in hydraulic lines etc. Daily FIW to well=555 bbls.Total FIW to well=555 bbls. 04/24/15-Friday Have welder extend flow nipple 20".Charge accumulator and flush back accumulator bottles.Flush oil through BOPS.Function test BOPs.Drain oil and fill accumulator tank back up.Charge system.Install flow nipple. RU to test BOPS.Test all BOP equip to 250 and 3000 psi.All equip passed.Test gas alarms.RD test equip and pull blanking sub.Witness of test was waived by Jim Regg,AOGCC. Test mud line to 2500 psi.Close blind rams.Pump FIW do tbg at 3 BPM,lined up to take returns to production off ann.Caught press at 25 bbls.Maintained 3 BPM and pumped 265 bbls before we got returns from ann.Started cleaning up at 290 bbls.Pumped a total of 360 bbls.Shut pump down. Install landing joint.BOLDS.Rig up Weatherford Power tongs. Pull and unseat tbg hgr @ 175K ,continue to pull up hole 4'with 200K to 205K.Pipe parted at the bottom of the coupling on the 1st joint 3 1/2 Supermax tubing below the tubing hanger pup joint.Lay down Tbg Hgr,XO pup jt and collar that parted from string,leaving tubing jt with 1/2 of pin end sticking up for top of fish @ 164'. Loss rate after unseating tubing hanger increased to 220 BPH then decrease to 2-3 BPH shortly after parting the tubing. Bottom of ESP was set @ 9,435'.Top of 4 1/2" scab liner top @ 9,547'(112')String fell estimated 112'+/-to top of 4 1/2" liner. Mobilize Baker Fishing hand and equipment.Tally 3 1/2" drill pipe on board.Prep to fish tubing. MU 7 1/2" OD overshot/cut lip guide shoe dressed with 3 1/2" grapple. Single in hole and engage TOF @ 164'. Work over and latch onto fish.PU hole 30'while gaining weight pulling up to 225K.Work pipe several times.Pipe parted again.POOH and recovered 14'of tubing fish. Perform crown inspection.All Good.Lay down Fish.MU 5 3/4" OD Over shot baited with packoff only to ensure we will be able to get over fish again with a grapple. RIH and locate TOF @ 176'.Work over fish 2'to 178'.MU head pin and 2" cement line.Pump down drill pipe @ 2 BPM, packed off at 250 psi.PU off fish and set back down with same results.Stand back drill pipe and lay down overshot.Mobilize Baker fishing shop to load out fishing tools.(Jars,subs etc.). While W/O Fishing Tools:House keep and organize rig areas.PU K elly and lower in hole to get measurements for needed air lines for K elly spinner.Located the cross over needed to make up the K elly hose.Make up Kelly Hose. Daily FIW to well=320 bbls.Total FIW to well=875 bbls. Loss Rate @ Report Time 5 BPH. 1. Hilcorp Alaska, LLC HileorpAlaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 04/25/15/15-Saturday Work on getting kelly rigged up,derrick inspection,and demobe projects while waiting on fishing tools.Hole taking 4 t/5 BPH.Get Kelly all rigged up and tested to 250 and 3000 psi on a chart.Good test.Set kelly back. PU BHA#3:5 3/4 overshot w/3 1/2 grapple and packoff,bumper sub,oil jars,3 DCs,Acc jars=127.11'and RIH to 159'and kelly up.Break circ at 3 BPM and 50 psi. Engage fish at 176' and slide do to no go at 181'.Pump at 3.5 BPM and 3100 psi through ESP.PU to 50k and bleed off jars.Work pipe up to 195k in 10 to 20k increments.Didn't see any movement at fish.Started getting gas back with a high of 340 units.Decided to circ through choke so we slacked off to 175k and closed the annular. Started getting traces of H2s back at the shakers w/a constant 300 units of gas.H2s alarm at shakers went off and well was shut in.All personnel mustered in the galley.All personnel accounted for.Production suited up and found 12 ppm H2S in pits.Leave well shut in and mobilize H2S scavenger to K ill the H2S. Monitor pressure on choke and DP while waiting on H2S scavenger to arrive.Also treat pits with NXS lubricant.Initial shut press at choke 43 psi and DP was 78 psi.Pressure after 2 hrs was 0 psi on choke and 35 psi on DP. H2S scavenger arrived.Set pallet in pits and mix in active system. Circulate surface to surface taking returns through choke manifold @ 3.5 bpm with 3050 psi.Circulate total of 630 bbls through choke manifold with 450 max gas units. Open bag and continue to circulate @ 3.5 BPM while working pipe to max pull @ 195K .Jar on fish staging up from 90K to 135K,straight pulling to 195K with no pipe movement. Straight pull and park with 195K up wt while pumping and spotting 37 bbls lube pill on backside. Pumps Down.Continue work pipe with max pull to 195K with no pump.Circulate charge pump across top of hole to keep hole full.Jar on fish multiple times staging up to 140K.(Max for Jars)Mobilize Pollard E-line Services. Attempt to release grapple from top of fish using multiple methods with no success. Circulate hole while holding 195K up wt on pipe. E-Line expediting 1-11/16" tubing cutter to pass through 2" ID Jars and Bumper sub. Daily FIW to well=117 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. 04/26/15-Sunday Been trying to release grapple from fish with no success.Decide to increase our pull to 90%of tbg strength.PU to 215k several times. About the 4th time the pipe parted at 210k.POH and had 20.65'of the bottom of the first full jt of tbg.Tbg parted about 1" into the collar on the 2nd jt.Have a tbg collar looking up at us.New TOF at 197'. MU 5 3/4 overshot w/4 1/4 grapple and RIH on 3 1/2 DP.RIH and tag cable on top of fish at 196'.Couldn't work over fish.POH and PU BHA#5:6X4 3/4 shoe,Extension,top sub,bumper sub,oil jars,3 DCs=118.83'. RIH to 186'.K elly up and break circ. Lost power to rotary.Found burnt wires in SCR.Rig electrician and platform electrician are trouble shooting electrical problems.{Work on demobe projects.Paint drillers door.Get steam going around rig. Replaced kelly swivel packing). Got rotary table power back but still no blower motor.Trouble shoot blower motor.Run secondary power cord for blower motor. Attempt to Mill over TOF with 6X4 3/4" Mill Shoe.Setting 10 to 15K down with no torque.Appear to be turning on junk.Did get pieces of ESP and control line cable over shakers.POOH and inspect Mill Shoe.No indication of milling on ID of shoe,but could see wear on the face of the Mill Shoe. Install Wear bushing. MU BHA#6:Rope Spear,XO Sub,Bumper Sub,Jars,3-4 3/4" DC's.RIH and Tag TOF @ 197'.Work spear down to 199'.POOH and recover 62#ESP Cable/Control line.Clean off spear and Re run spear tagging this time @ 199'Work down to 201'.Acted like we were along side of tubing @ 201'.POH with spear and no recovery. PU BHA#8:6X4 3/4 shoe,Extension,top sub,bumper sub,oil jars,3 DCs=118.83'.RIH and tag TOF @ 199'.Rotate and wash over fish to no go @ 206'.POH and Lay down Mill Shoe BHA.MU BHA#9:5 3/4 overshot w/4 1/4 grapple.RIH with Grapple on Drill Pipe only.Latch on to Fish.PU and Park with 125k UP WT. Rig up E-Line.RIH with Tubing punch on CCL.Set down @ 9,352'WLM(Top of Pump assembly).PUH logging CCL from 9,352'to 7,899'.Park @ 7,899'CCL,placing top shot @ 7,904'and bottom shot @ 7,906'.(2' of shots with 11 shots total).Punch tubing.Paint Depth flag on E-Line and POOH with tubing punch. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. Hilcorp Alaska, LLC HileurpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 04/27/15-Monday POOH with tubing punch after punching tubing @ 7,904'(106'above 7" liner top).MU and RIH with 2" RTC tubing cutter.Log into CCL from 8,165'and tie into short jt @ 8,127'.Park @ 7,897.7'CCL,placing cutter head @ 7,904'.Initiate detonation sequence with no indication of detonation.Repeat sequence.RIH and log up past 7,904'looking for severed pipe.No indication.POOH with RTC cutter. Check tool.The thermal gen resistance was low so they swapped out the firing head.RIH and correlate to get on depth.Fire RTC cutter at 7,904'.Had good indication that it fired at unit and driller could feel the shot go off at the pipe.POH w/cutter. While we were POOH we noticed that all the collars were 2'higher now.With that info we decided to just run back in with the jet cutter and not move the tbg.Changed their tools and RIH w/a jet cutter.Correlate and cut cable at 7,904'.POOH and RD e-line. Pull up to 107k for about 20' then the wt fell back to 100k.Stand back DP and lay dn overshot.Tbg had a big ball of cable and control line about 6'dn from the box.It also had a clamp in the middle that was missing the top band. RU sheaves for control line and cable.POOH laying dn 3 1/2 Supermax tbg.Ended up that we couldn't put the cable back on the spool because it was balled up at the clamps and wrapped around the tbg tight.Cut the cable and control line in small enough sections to put in a dumpster.Laid dn 1,400'of pipe at 1700 hrs. Continue POOH laying down tubing and cutting cable and control line and throw in dumpster.121 jts laid down @ 23:30.(4,022')(113 jts left in hole to lay down)(43 jts on top of fish @ 7,904').So far 64 whole Cannon clamps,1 twisted clamp and 1 splice clamp retrieved.Continue POOH laying down tubing from 3,680'and cutting cable and control line and throw in dumpster.Cable and flat pak not twisted after 183 jts.Started seeing deformalities such as bent or bulged tubing @ 163 jts out.(5,400'in+/-). Rig up to spool cable on reel.Continue to POOH spooling cable on reel and laying down tubing from 1,700'to 1,200'. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. 04/28/15-Tuesday Continue POOH spooling cable and laying dn bent tbg.Laid dn 232 jts and a 9.10 stub.Should be a 24.12 cut off sticking up w/a cannon clamp on the collar at the bottom.Cable parted just under last cannon clamp so there is at least 40'of cable above the cut.New top of fish 7,904'WLM. Clean rig floor and get tbg ready to ship out. MU BHA#10: Crankshaft Rope Spear,Double Pin Sub,Bit Sub W/Float, Bowen Lub.Bumper Sub,Bowen Oil Jar,XO Sub,9-4 3/4 Drill Collars.Total length= 312.45. TIH picking up 3 1/2" Drill Pipe from 312' to 4,880'.Drift and tally pipe in V-Door with 2 5/16" Drift. Fill pipe and CBU from 4,880'@ 8 BPM with 1950 psi.Circulated 340 bbls with max gas @ 95 units. Continue TIH picking up drill pipe from 4,880'to 7,831'.(237 jts total).Pick up K elly. CBU @ 8.5 BPM with 2400 psi.Max gas units @ 107. Establish parameters with 175K PU and 97K SO.Slack off with no pump or rotation from 7,836'. Started taking weight @ 7,873'.PUH to 7,831',SO with rotation @ 5 RPM and no pump.Work K elly down to 7,873'.Park @ 7,873'while rotating.Noticed 5K increase in weight while rotating.PUH with 5K over before falling back to original up wt @ 175k.Make connection and work down to 7,896'.Started taking weight @ 7,896'and not drilling off.PUH with no over pull this time.Set back K elly and lay down 1 jt.(238). POOH from 7,831'standing back 3 1/12" Drill pipe. Stand back 9-DC's work BHA.Recovered 95 lbs,balled up/tangled up ESP cable/control line.Cut fish off Crankshaft rope spear for re-run. Clean and clear rig floor. Service Rig. MU and RIH with BHA #11: Crankshaft Rope Spear,Double Pin Sub,Bit Sub W/Float,Bowen Lub.Bumper Sub,Bowen Oil Jar,XO Sub,9-4 3/4 Drill Collars. Total length= 312.45'. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. Hilcorp Alaska, LLC HikvrpAlaska.LLC Weekly Operations Summary Well Name API Number _Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 04/29/15-Wednesday Continue Rih w/bha#11 P/up working pup and single t/7,878'and kelly up. Brk circ&circ btm up @ 8 bpm @ 2150 psi w/high gas of 94 units.do pump.Well still static. Work tools f/7,878't/7,896'attempting to clean top of fish of cable,flatpack junk.Unable to pass 7,896'.Set kelly back. Pooh t/bha#11 @ 312'. Work bha#11.No recovery,chk&clean spear 2nd set spear barbs shows signs of being inside of tbg.L/dn bha#11. TIH from 312'to 7,833'PU single and K elly Up. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. P/up and M/up Bha#12=8-1/8" 0/shot w/cut lip guide loaded w/3.5" grapple and MCP+bumper sub+ Oil Jar+(9)4-3/4" dcs+XO+Acc Jar+XO=314.45'. Establish parameters @ 6 BPM,925 PSI,Up Wt 125K ,Dn Wt 101K,Rot Wt 110K @ 17 RPM with 1.5K torque. Establish Parameters @ 3 BPM,275 psi,Up,Dn,Rot Wt same. 17 RPM with 1.6K TQ.Tag TOF @ 7,896'. Attempt several times and methods to work over top of fish.Had max over pull of 10K a couple times.Appear to be just snagging TOF with the grapple.Last over pull was 5K before pulling off TOF.Set back Kelly,LD Single. TOH from 7,833'to 314". Work BHA,stand back DC's.Lay down and inspect overshot.Mill control showed signs of wear and had shards of SS control line embedded in the teeth. The Grapple showed signs of contact at the start of the grapple where we may have had a slight bite on the fish. MU BHA#13:8 1/2 x 4"Rotary Shoe,X Over Bushing,Washpipe Ext,Top Sub,XO Sub,Double Pin Sub,Bit Sub W/Float,Bowen Lub.Bumper Sub,Bowen Oil Jar,XO Sub,9-4 3/4 Drill Collars.Total Length=309.61'. TIH from 312'to 596'. Service rig. Continue to TIH from 596'to 7,860'.PU Kelly. Break circulation @ 5 bpm with 730 psi,Up wt 122K,Dn wt 100K,Rot Wt 107K-40 RPM,@K free TO.Tag TOF with no rotation @ 7,894'.Wash down over fish with no rotation or obstructions to no go @ 7,901'.Set down 10K @ No Go.Repeat same while rotating over top of fish.Set down 5K while rotating momentarily with no drill off.Pick up off fish was clean.Set back K elly.Monitor well. TOH from 7,860'to 312'.Work BHA,L/D single and Accel jar,stand back DC's. 04/30/15-Thursday Continue work Bha#13.Missing 8-1/2" X 4"burning shoe and XO bushing had come-a-part @ top threads of XO bushing.Total 2.51' left in hole. M/up Bha#14=RR#12=8-1/8" 0/shot w/cut lip guide loaded w/3.5" grapple and MCP+bumper sub+Oil Jar+(9)4- 3/4"dcs+XO+Acc Jar+XO=314.45'. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. Rih w/ bha#14 F/314'to 7,833'.PU single and K elly Up. TOH from 7,834'to 314'. L/dn and inspect Bha#14 Pack off washed and no sign of grapple engagement. Establish parameters @ 6 BPM,930 PSI,Up Wt 125K ,Dn Wt 101K,Rot Wt 110K @ 17 RPM with 1.5K torque. Establish Parameters @ 3 BPM,275 psi,Up,Dn,Rot Wt same.17 RPM with 1.6K TO.Tag TOF @ 7,898'. Attempt several times and methods to work over top of fish.Had max over pull of 2K a couple times.Did have pack-off engage w/+300 psi over. Set back K elly,LD Single. Monitor well,static,and service rig. Service rig. P/up m/up Bha#15=8-1/2" x 3-1/2" burning shoe+XO bushing+8-1/8" o/shot bowl+bumper sub+oil jar+XO+(9)4-3/4" dcs +XO+Acc Jar+XO=316.95'. Establish parameters @ 6 BPM,950 PSI,Up Wt 125K,Dn Wt 101K,Rot Wt 110K @ 25 RPM with 1.5K-2K torque.Establish Parameters @ 3 BPM,265 psi,Up,Dn,Rot Wt same.25 RPM with 1.6K-2K TQ.Tag TOF @ 7,895'with 10K and no rotation.Bring on Rotary with 3 BPM parameters,2K WOB.Mill on and pass over top of fish.Work Grapple over TOF @ 7,901'.Straight pull in 25K increments to 225K (100K over). Jar on fish staging up from 175K to 225K.Hit jars 23 times.Straight pull to 250K,80%max pull of 2 7/8" eue connection on bolt on discharge.Weight broke over @ 250K.PUH 30'with 25K additional string weight. TIH from 317'to 7,835'.PU single to 7,868'.MU K elly. TOH from 7,835'to BHA. CBU @ 8.5 BPM with 2050 psi.Max gas units @ 429.Pumped 657 bbls.Monitor Well.Set back K elly,L/D single. Work BHA:Lay down Accel jars,Stand back DC's.Break down and lay down bumper sub and jars.Pull Fish to surface.Appear to have recovered all tubing.Cable was balled up on top of Cannon Clamp below cut joint.Lay down over shot assembly with cut joint and mill shoe that was left in the hole yesterday. Rig up Weatherford tongs.POOH laying down tubing and cutting ESP cable and flat pak in sections and place in d u m pste r. Hilcorp Alaska, LLC Ilileorp Alaska.LLC Weekly Operations Summary Well Name API Number _Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/01/15-Friday Continue POOH laying down tubing and cutting ESP cable and flat pak in sections and place in dumpster.Recovered all tbg(43 jts)and bolt on discharge head sheered bolts on same.Recovered all cable.May have 1'of mtr lead and(2)30'chem lines above TOF New ETOF =9,350.15'.Well still static. Clear clean rig floor.Power wash throughout rig cleaning up mess from pull while monitoring well still static. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. Brk 0/shot from fish l/dn same.P/up bha#15=Rope spear w/5-3/4" stop+XO+bit sub w/float+Bumper sub+Oil jar+(9)4-3/4" Dc's=307.09'. Rih w/bha#15 p/up rabbiting and strapping 48 jts 3-1/2" s-135 dp 13.3#. Continue rih w/bha#15 w/dp out of derrick t/9,315'and kelly up. Establish parameters @ 5 BPM,850 PSI,Up Wt 142K,Dn Wt 110K,Rot Wt 115K @ 15 RPM with 1.5K torque.Establish Parameters @ 3 BPM,275 psi,Up,Dn,Rot Wt same.15 RPM with 1.5K TO.Tag TOF @ 9,343'with no rotation.PUH and establish rotation with rope spear,slack off and tag TOF while rotating 15 rpm.K ill rotary,PUH and repeat tagging TOF while rotating 15 rpm. PUH full kelly to 9,315'.CBU @ 9 bpm with 2720psi and no gas units.Monitor well,Well static.Set back K elly.P/U single. TOH from 9,315'to BHA.Rig up test equipment.Flood and purge air from choke.Test choke manifold valves 3,15 and 16 while working BHA. Work BHA:Lay down Accel jars,Stand back DC's.Break down and lay down bumper sub and jars.Pull Rope spear to surface with no recovery.Lay down Rope Spear BHA.Clear and organize rig floor. Build test joint,pull wear Bushing.PU K elly and flush stack.Function test BOP.Set test plug.Rig up test equipment.Flood stack to choke manifold.Trouble shoot leak.Pull and reseat test plug.Obtain good test on Lower Pipe Ram. Test BOP and associated equipment as per SUNDRY to 250/3000 psi to 3 1/2" pipe size.Test witness waived by Jim Regg,AOGCC. 05/02/15-Saturday Continue Testing BOP and associated equipment as per SUNDRY to 250/3000 psi to 3 1/2" pipe size.w/no failures.Test witness waived by Jim Regg,AOGCC on 4-30-15 @ 11:58 AM. R/dn test equipment.Test gas alarms.Set wear ring.Service over riding clutch and adjust brakes.Had false h2s gas alarm.Secured well and equipment and all hands mustered and accounted for. Daily FIW to well=0 bbls. Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. P/up Bha#17=6" X 4-3/4" burning shoe+5-3/4" wash pipe ext+XO bushing w/finger bsk+5-3/4" ROB+bumper sub+oil jar+(9)4-3/4" DC's.RIH t/9,315'and kelly up and brk circ. Set kelly back and slip cut 154'drlg line and repair bolts on RT inspection.Cover and chg/out oil RT gear box. POOH with BHA#17 from 9,312'to 306'. Work BHA,inspect rotary shoe and reverse circulate junk basket.Recovered 13 lbs of balled up flat pak and single control line up inside the rotary shoe.Lay down rotary shoe and ROB. Drop ball and pump ball to seat @ 5 bpm @ 1050 psi.Ball on seat @ 2020 psi and initiate reverse thru junk bsk w/high kelly and shoe @ 9,279'reverse dn t/9,309' and engage kelly while Establishing parameters Up Wt 142K,Dn Wt 110K,Rot Wt 121K @ 15 RPM with 3.2K torque. Continue reverse dn tag @ 9,342'dress fish w/rotation f/9,342't/ 9,347'using reverse bsk in attempt to clear junk for 0/shot. MU BHA#18:5 3/4 Bowen Overshot,Bowen Lub.Bumper Sub,Bowen Oil Jar,Pump Out Sub,9-4 3/4 Drill Collars,Bowen Acc.Jar.Total BHA Length=310.67'. TIH from 310'to 9,319'. MU K elly. Hit jars 10 times staging up from 25K over to 50K.Lost bite with grapple.Work back over fish setting down 20K .Stage up to 190k straight pull. (50K over).Hit jars 10 more times staging up from 35K over to 50k over.Weight fell off when jars hit at 50K over.PUH with 15K over pull then fell back to 10K over pull.Continue PUH to high kelly with 10K over.Gained 10K string weight to 150K Up Wt. Circulate Bottoms up from 9,315'@ 8 bpm with 1981 psi.Set back K elly.Monitor well.Well static. Establish parameters @ 6 BPM, 1110 PSI,Up Wt 140K,Dn Wt 110K,Rot Wt 120K @ 15 RPM with 1.5K-2K torque.Tag TOF @ 9,343'with pump on and no rotation.Pressure increased 100 psi.PUH and break off K elly.Drop bar and shear open circulating sub.Work Grapple over TOF @ 9.343',set 20K down. Straight pull staging up to 190K (50K over). TOH slowly with fish from 9,315'to 5,500'@ report time. Hilcorp Alaska, LLC Hi!corpLLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/03/15-Sunday Continue to POOH slowly in and out of slips easy with fish. Work BHA. L/dn fish.Recovered(5)Pump sections&recovered 19 of 24 clamps(thinking(5)missing clamps were pulled off the tandem 4"seals due to recovery.Complete 29'below fish of Mtr lead to pot head.It still had crimp on ends w/cable armor still intact)also recovered 54'-8"of gauge control line below fish and only 20'flat pack below fish(looks like that had a come-a-part @ pot head area). New ETOF @ 9,448'(top of 400X Vortex intake bolts sheered at flange &shaft coupling missing). Monitor static well and Power wash and clean work areas.Perform rig Maintenance while waiting on Slick line hands. Slick line hands on board.Go over job,lay out work scope.PJSM.R/up slick line open hole w/1-3/4" tool string. Rih# 1=5.4"centralizer and 4" Rare earth magnet t/9,434'wlm.Pooh,recovered 4 lbs of metal debris&recovered missing shaft coupling. Had false fire alarm.Secured well&equipment and all hands mustered and was accounted for.Rih#2=RR#1 t/9,434'wlm.Pooh, recover 2 lbs of metal debris(2 sm pieces of clamp hinge). R/d slick line. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. MU BHA#19:Rotary Shoe 6" x 4",Washpipe Ext, X Over Bushing w/Finger Baskets,5 3/4 ROB,Bowen Lub.Bumper Sub,Bowen Oil Jar,9-4 3/4 Drill Collars.Total length=306.36'. TIH from 306'to 9,410'.P/U 8.10'Pup Joint ro 9,418'. Drop Ball for RCJB.PU and MU Kelly. Drop ball and pump ball to seat @ 5 bpm @ 1050 psi.Ball on seat @ 2050 psi and initiate reverse thru junk bsk w/high kelly and shoe @ 9,418'.Engage kelly while Establishing parameters Up Wt 142K ,Dn Wt 109K,Rot Wt 120K @ 40 RPM with 3.2K torque.Continue reverse do tag TOF @ 9,448'.Wash over fish to 9,453'.PUH off fish with 2 bobbles,1 @ 5K over and 1 @ 10K over. While wire lining Drained rotary table&flushed w/diesel&refiled w/oil and additive. Bring on rotary with above parameters,mill over and dress fish w/rotation f/9,448't/9,453'.Started taking weight @ 9,453'. PUH off fish looking for over pulls. Repeat 3 times until clean P/U @ 140K.Set Back Kelly.Lay down Pup joint and PU single.Monitor static well.No gas units @ Bottoms up stks while milling. POOH from 9,410'to 306'.Pipe pulling wet. Work BHA,Stand back DC's.Inspect and lay down Rotary shoe and RCJB. Recovered 6'+/-of control line from inside rotary shoe.Finger baskets had small chunks of rubber shield from flat pak control line. MU BHA#20:5 3/4 Bowen Overshot,Bowen Lub.Bumper Sub,Bowen Oil Jar,Pump Out Sub,9-4 3/4 Drill Collars,Bowen Acc.Jar.Total BHA Length=310.67'. TIH from 310'to 6,100'@ report time.ETOF @ 9,448'. 05/04/15-Monday Continue TIH from 6,100'to 9,417'.Drop bar for circ sub.Grab K elly. Pump bar on seat and shear open circ sub.Establish parameters @ 6 BPM, 1220 PSI,Up Wt 140K,Dn Wt 110K.Work Grapple over ETOF @ 9,448',set down @ 9,457'with 20K down.Bleed Jars @ 25K over.Straight pull staging up to 175K (35K over)to ensure grapple engagement. Fire jars staging up from 35K over to 75k over.(215K)free fish @ 3k heavy.Set kelly back.Monitor well,static. Pooh to bha.L/dn accelerator jar(wore out hanging open). Work bha.L/dn fish.Recovered 400X vortex intake+(1)seal section+adapter @ 11.08'-total recovery(missing shaft coupling)also had two clamps on same.New ETOF @ 9,459'. R/up slick line open hole w/1-3/4" tool string.Rih #1=5.4" centralizer and 4" Rare earth magnet t/9,445'wlm. Pooh recovered 1 lbs of metal debris and recovered missing shaft coupling.Rih#2=RR#1 t/9,445'wlm.Pooh recover 1 lbs of metal debris.R/d slick line. MU BHA#21:Rotary Shoe 6" x 4",Washpipe Ext, X Over Bushing w/Finger Baskets,5 3/4 RCJB,Bowen Lub.Bumper Sub,Bowen Oil Jar,Pump Sub,9-4 3/4 Drill Collars.Total length =308.04'. TIH to 7,819'. Slip and cut 190'Drill line. Continue TIH from 7,819'to 9,444'.Grab K elly. Circulate 1 DP Volume,Break off Kelly and drop 7/8" ball to activate ROB.Pump ball to seat @ 5 bpm @ 1050 psi.Ball on seat w/2100 psi.Initiate reverse thru junk bsk w/high kelly and shoe @ 9,444'.Engage kelly while Establishing parameters Up Wt 143K ,Dn Wt 106K,Rot Wt 123K @ 40 RPM with 3.2K torque. Wash down with no rotation taking weight and falling off @ 19'in on kelly.(9,463').Continue wash down additional 2'to 9,465'(21'Kelly in).PUH 10'and establish rotation with above parameters.Mill over top ETOF @ 9,463'to 9,465'.Started taking weight and no drill off @ 9,465'with slight torque swings.PUH off fish with no issues.Repeat milling to 9,465'with same results.Monitor static well.Set back Kelly. TOH to 9,300'. Pipe pulling Wet.Drop bar and open circulating sub pumping 1 DP Volume.Platform Gas Alarm. Secure well,all hands muster.Production call all clear. Continue TOH from 9,300'to 306'. Work BHA#21,Stand back DC's.Inspect and lay down Rotary shoe and ROB.Recovered 5'+/-of control line flat pack from inside rotary shoe.Finger baskets had no recovery. Service Rig. MU BHA#22:5 3/4 Bowen Overshot,Bowen Lub.Bumper Sub,Bowen Oil Jar,Pump Out Sub(Open),9-4 3/4 Drill Collars, Bowen Acc.Jar.Total BHA Length=310.67'. TIH from 310'to 2,300'@ report time. Daily FIW to well=0 bbls.Total FIW to well=437 bbls. Loss Rate @ Report Time 0 BPH. • Hilcorp Alaska, LLC Hi[carp Alaska,ld./: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-1SRD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/05/15-Tuesday Continue rih w/Bha#22 t/9,445'and Kelly up. Brk circ @ 5 bpm @ 780 psi.Establish parameters Up/dn/rot 142/110/120k.Engage fish w/20k do wt t/9,466'.P/up w/over pull t/30k over and bleed jars.Straight pull t/50k over and set grapple.Fire jars once @ 55k over and freed fish w/5k heavy.Well started taking fluid. Bring pump on line 8 bpm @ 1975 psi and catch up w/losses w/initial loss rate @ +200 bph.Circ STS w/loss rate of 116 bph and no gas.Put well on trip tank w/static loss @ 90 bph.Rack back K elly. TOH from 9,445'to BHA.Keeping hole full and monitor loss rate. Work Bha.L/dn fish and recovered remaining ESP components, 1 seal section,2 motor sections,gauge sub and anode,along with control line and all clamps.2 clamps on seal section and 11 clamps on tandem motor section. Lay down BOT fishing tools. Daily FIW to well=1085 bbls.Total FIW to well=1522 bbls. Loss Rate @ Report Time 0 BPH. Clear and clean rig floor. MU BHA#23:8 1/2" Bit No Jets,7" Boot Basket,9 5/8 Casing Scraper,7" Boot Basket,Bit Sub W/Float,XO Sub,Bowen Lub.Bumper Sub,Bowen Oil Jar,9-4 3/4 Drill Collars. TIH with scraper from 312'to 6,200'. CBU @ 9 bpm with 2200 psi and 60 bph loss rate while circulating.No gas @ bottoms up.Monitor well with 54 bph loss rate. TOH from 6,200'laying down 96 jts 3 1/2" drill pipe.TOH standing back remaining 30 stands drill pipe. Work BHA:Stand back DC's Break off bit,break down boot baskets with no junk recovery in baskets.Lay down all BOT tools including bumper sub and jars.Clear and organize rig floor.Stage HES Retainer and running tools on rig floor.Reconfigure HES Retainer with plug for bridge plug application. MU HES Bridge Plug Assembly.TIH from surface to 6,103'. Initiate setting sequence rotating to right 35 turns.Stage up to 50K over in 10K increments.Shear off of CIBP,placing the top of plug @ 6,100',center of element @ 6,101'and bottom of CIBP @ 6,103'.RU to pump down drill pipe,close upper pipe ram and test casing from top of plug to surface to 1500 psi.Test good.Bleed off. 05/06/15-Wednesday Prep and pooh.L/dn 3-1/2" dp,total 129 jts and stage bundles for boat.Rih w/(9)4-3/4" dcs&I/dn same&prep for boat. Pooh std back 21 std 3-1/2" dp.Chk L/dn running tool(ok). Daily FIW to well=264 bbls.Total FIW to well=1786 bbls. Loss Rate @ Report Time 0 BPH. Clean clear floor. R/up E-line. Rih w/GR,CCL&CBL tool suite.Log CBL from 6,100'to 180'.Rig down E-Line.Send logs to town. Work on demobe projects and house keeping while doing E-Line. Work boat and off load tubing and completion jewelry.Off load perf guns and mud products.Lay out,rack and tally 3.5 supermax tubing. Production utilizing crane.Continue to work on demobe projects and housekeeping throughout rig areas while waiting on the crane to PU tubing. 05/07/15-Thursday Load door w/tbg.P/up Rih rabbiting 3-1/2" 9.2#L-80 super max tbg. Daily FIW to well=264 bbls.Total FIW to well=1786 bbls. 20" x13-3/8" =10 psi,13-3/8" x 9-5/8"=165 psi.Loss Rate @ Report Time 0 BPH. Shipped 721 bbls to Trading Bay. M/up XO,rih w/tbg on 3-1/2" dp out of derrick t/6,061'. Circ and wait on production to chg over well t/3%K CL.Test 9 5/8" Casing from 6,100'(Top of CIBP) to surface to 1500 psi for 15 minutes.Good test. Displace well to 3%K CL staging up to 4 BPM taking returns to Production.Pumped total of 721 bbls to Trading Bay Production. TOH laying down 30 jts 3.5" DP.Continue TOH standing back 11 stands 3.5'DP.Start cleaning pits. Change over to 3.5 tubing handling equipment.TOH standing back 41 stands 3.5" Supermax Tubing.Continue cleaning pits. Clean and clear rig floor.PJSM on slip and cut drill line.Continue cleaning pits. Slip and cut 130'drill line.Continue cleaning pits. Build test joint,pull wear bushing.PU K elly and flush stack.Function test BOP.Set test plug.Rig up test equipment.Flood stack to choke manifold. Hilcorp Alaska, LLC HileorpAlaAa.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/08/15-Friday Continue to rig up test equipment.Flood stack to choke manifold.Obtain good shell test.Continue cleaning pits. Test BOPES as per sundry 250L-3000H.Johnny Hill w/AOGCC on location to witness testing.Had(2)gas alarms and full muster.Also about 1/2 way thru test had pull test plug chg/out test plug 0-ring.Encounter leak off while attempting to test remaining choke valves.Also slight drip from annulus.Trouble shoot leak attempting multiple test on choke manifold both with and without test joint in the hole. Daily FIW to well=264 bbls.Total FIW to well=1786 bbls. 20" x13-3/8" =10 psi,13-3/8" x 9-5/8" =165 psi.Loss Rate @ Report Time 0 BPH. Shipped 721 bbls to Trading Bay. Isolated test pump from BOP stack attempting to test choke valves with same results.Some test bleeding slower than others,with visible drips from Choke Manifold Panic line tattle tail valves.Isolate choke manifold valve by valve, attempting to locate bad valve.Suspect CMV#13 and possibly#8 and#9. Re-land test jt.Isolate from Choke manifold with Choke and Kill line NCR's shut. Attempt to test Bag with good low test but leak off on high test.Dump 6 sacks oil field salt on top of test plug.Re test Bag on high test and achieve good test.Open CHCR,re-flood choke manifold,attempt test on Bag against CMV's 2,6,(13),5.No Test.Re-test Bag against 2,6,(4),5.Good Test.Test 1,7,12,4, 14 against UPR.Good Test.Attempt to test 8,9, 10,and 11 against UPR and 13.No Test. Observing leak out tattle tail valves on Panic line flange.Dump 3 sack oil field salt on top of test plug.Pull test joint. Close Blind Rams.Achieve good test on Blind rams against CMV's 4,6,2. Attempt low test on 4,8,9 with blinds.No test.Leaking out tattle tail on Panic line. Rebuild CMV#13.Signs of washout on seats and gate.Rebuild Valve#8.Seats and gate bad.Re-assembling valve#8 @ report time. Pass test's on:Blind Ram,Upper Pipe Ram,Lower Pipe Ram,Bag,4" Kill,Kill HCR,Choke HCR,Man Kill,Man Choke,Dart Valve,TIW,CMV's 1,2,3,4,6,7, 12, 14, 15, 16. After repairing CMV's 5,8,9 and 13,test same along with 10 and 11. 05/09/15-Saturday Continue re-assembling CMV#8 valve.Flood choke manifold and work air out of same and noticed fluid just bypassed CMV#8. Disassembled same and chg/out gate for correct one.Re-flood and work air out same.Attempt test(bonnet leaking on CMV#8)pull bonnet chg out seal also chg/out complete CMV#5 and#3. Flood choke manifold and work air out of same test#1 Blind ram,CMV#3, 8,9, 10,11,13 and lower kelly valve 250-3000 psi(Good).Test#2 Blind ram,CMV#5, 10, 11,13 and Upper kelly valve 250-3000 psi (Good).R/dn test equipment,set kelly back.Pull test plug and set wear ring. Daily FIW to well=264 bbls.Total FIW to well=1786 bbls. 20"x13-3/8" =10 psi,13-3/8" x 9-5/8"=165 psi.Loss Rate @ Report Time 0 BPH. Clean and organize rig floor and choke house. PJSM. Rig up Perf Gun Handling Equipment.MU Safety Joint.PU and RIH with 446'4 1/2" ,5 SPF,60 deg Phasing,RDX Perf Guns. MU Mech Fire Head,1 jt 2 7/8" tubing,Ported flow sub w/debris disc,2 jts 2 7/8" tubing,RA Marker Sub,XO 2 7/8" eue x 3 1/2" eue,XO to SM tbg.Total TCP BHA=558.56.RA Marker to top shot=108.72'Top Shot will be @ 4,672'to 5,118'. TIH with Perf guns on 3 1/2" Supermax tubing from 558'to 4,624'.XO to 3 1/2'DP.Continue TIH from 4,624'to 5,198'with 3 1/2" DP.POH laying down 2)jts 3 1/2" DP and park @ 5,133'+/-bull plug depth.Pu Wt 64K ,Dn Wt 47K. Rig up E-Line to correlate guns on depth.RIH with GR/CCL.Log RA Marker 1.50'deep @ 4,564.50.Placing top shot @ 4,673.50'.Need to move up hole 1.50'.Send Correlation log to Geologist and receive confirmation to move up hole 1.50'.Rig down E-Line. MU Bar drop/Safety valve assembly.PUH 1.50' Placing RA Marker @ 4,563'with Top Shot @ 4,672'to 5,118'.Close Annular,fill surface equipment from choke to pits.Line up to circulate down string.Drop Bar and fire guns with indication of detonation after 2 minutes,15 seconds. Bring on pump,staging up to 6.5 bpm 750 psi,taking returns through full open choke.Caught returns @ 4.2 bbls pumped.Circulate 2 hole volumes through full open choke with max gas @ 200 units and 0- 12 bph loss rate.Open bag and monitor,well breathing.Bring on pump and circulate STS staging up to 8 bpm,940 psi,with 250 max gas units.Monitor static well. Hilcorp Alaska, LLC HiI orpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/10/15-Sunday Rih w/3-1/2" dp from derrick t/5,669',bull plug depth,and brk circ f/ported sub depth of 5,185'(67'below btm shot of 5,118').Circ btm up @ 9 bpm @ 1270 psi w/max gas of 248 units. Monitor static well on trip tank w/no losses. Circ @ 6 bpm @ 600 psi and weight up complete circ system f/8.6 ppb t/9.0+ppb(w/252 unit gas spike @ only 170 bbls in to circ). Monitor static well on trip tank w/4 bph loss rate. Circ btm up @ 9 bpm @ 1270 psi.Chk gas units and rig service gas units 20. Daily FIW to well=0 bbls.Total FIW to well=1786 bbls.Total KCL to well=59 bbls 20" x13-3/8" =10 psi,13-3/8" x 9-5/8" =165 psi.Loss Rate @ Report Time 2.5 BPH. Pooh I/dn all 3-1/2" dp total 33 jts and(3)jts 3-1/2" super max tbg. Continue pooh std back 40 std 3-1/2" super max tbg. MU safety joint. PJSM on laying down Guns.POH laying down 4 1/2" perf guns.All shots fired.Losses to well @ 4 bph. Break Down Safety Joint.Clean and clear rig floor. Pull Wear Bushing.Rig up to run Completion.Rig up control line equipment.Hang sheave. MU Packer Assembly: WLEG,X Nipple,2.81" Profile w/RHCP Plug,9 5/8" Liner Top Packer,Tie Back Sleeve,Anchor latch with Seals w/M/S(Effective Length .73),Chemical injection Mandrel with pups.Tie in control line to chemical injection mandrel.Test line to 5000 psi for 15 min.Good. Run in hole with 3 1/2" Supermax tubing from derrick installing jewelry as per tally.Install(1)SS band on control line every joint to 1st GLM(39 bands total below GLM),and every other joint to surface.Test SSSV to 5000 psi for 15 min good test. Ran Completion as Follows:Tri Point Liner Top Packer/X nipple tail pipe assy,Chemical injection Mandrel w/pups,36 jts Tubing,GLM 1 w/pups,21 jts Tubing,GLM 2 w/pups,54 jts Tubing,BOT TE-5 SSSV w/2.812 BX Profile/pups,8 jts Tubing,Tbg Hgr w/pup.Ran 119 total jts 3 1/2" Supermax.Making Up Tubing hanger @ Report Time.Loss rate @ 2.5 BPH @ Report Time. 05/11/15-Monday Continue running Gas lift completion w/3-1/2" 9.2#L-80 tbg out of derrick installing bands every other Jt on chemical injection line f/ 3,760't/4,040'.L/dn top single off std#40. M/up 3-1/2" dp landing jt.P/up m/up hanger. Dress hanger w/SSSV control line and Chemical injection line and repressure SSSV line t/4000 psi and cap chemical lines. Flush all HP lines and equipment w/drill water. Clean&drain pits,Drain Bope stack and land tbg hanger w/WLEG @ 4,083.65'RK B with just pipe up wt of 29k and do wt of 24k.Ran total 119 jts and installed(93)1/2" SS bands on chem and sssv control lines. Daily FIW to well=0 bbls.Total FIW to well=1786 bbls. Total KCL to well=59 bbls 20" x13-3/8" =10 psi,13-3/8" x 9-5/8" =165 psi.Loss Rate @ Report Time 2.5 BPH. Confirm hanger.Land out(ok).RILDS and pack-off hanger in DCB spool and Test t/5000 psi.R/up head pin and circ hose for prk set. Drop bar and pressure up tbg t/3500 psi and hold for 30 min.Saw multiple prk shifts while pressuring up and set prk @ 4,054'. Bleed off pressure slow.R/dn circ hose and blow dry.R/up on back side to test prk and csg. Pressure up on Tbg X 9-5/8" annulus w/tbg open t/1550 psi on chart for 30 min w/no bleed off(good test). Bleed off pressure.R/dn test equipment.Bleed off SSSV control line and close valve,cut plug same. Brk/dn and l/dn landing jt.Finish testing annulus valve.Remove VR plug and set BPV.P/up kelly.Flush kelly w/drill water&set back same. Bleed down Koomey,pull master bushings,flow nipple,air boot flanges&mouse holes.Rig up bridge crane to bag.Remove and blow down Koomey lines back to tank.Measure and mark line accordingly and coil up on rig floor for storage. Work boat and back load mud products,drill pipe etc..Remove flow lines,continue cleaning pits.Drain pits to production.Cleaning on shakers. Start to NU Tree section x section.Continue cleaning and removing rams from double and single gate while N/U tree. Testing Tbg Head Adapter Void to 5000 psi and removing rams from double gate @ Report time. Start N/D and pickle BOPE Stack.Clean protect,preserve and prep for boat.Removing Double Gate @ Midnight. Continue to N/D BOP.Remove and set Doublegate aside,remove mud cross and single gate from cellar.Remove rams from single gate,clean same.Stage tree components on rig floor.N/D and lay down drill riser to allow for Tree installation while cleaning and removing rams from double and single gate. Hilcorp Alaska, LLC HileorpAlaska.UAL: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 4/23/2015 5/12/2015 Daily Operations: 05/12/15-Tuesday Continue Testing Tbg Head Adapter Void to 250/5000 psi(good test).Remove rams from bopes,cleaning and pickling same.Prep for boat and cleaning pits while stacking up tree and torque.Pull BPV&set TWC and shell test tree 250-5000 psi(good).Hang choke. R/up slick line and confirm SSSV locked open&test lubricator 2000 psi.Run#1.Retrieve drop bar.Run#2.Retrieve dummy from chemical Injection mandrel at 4,028'.Run#3.Retrieve dummy valve from GLM at 2,826'.Run#4.Retrieve dummy valve from GLM at 2,118'. Start demobe of rig#56.Off load empty baskets off boat and load out BOP equip on the boat.Blow do accumulator lines.Pull lines to rig floor and coil up in pallet boxes.Continue cleaning pits. Slickline Run#5.RIH and set live valve in GLM at 2,118'.Run#6.Set orifice valve in GLM at 2,826'.Run#7.Set valve in chemical Injection mandrel at 4,028'.Run#8.Pull RHC plug from X-nipple at 4,071'.Rig down slickline,and turn well over to production. V of:,Ty J hs,r—Ai/7,-t' THE STATE Alaska Oil and Gas .st' =- �� '� o Conservation Commission .� is __ __ AI .ASIc;A `•if it =-- 333 West Seventh Avenue 0.0 GOVERNOR BILL WALKER Anchorage. Alaska 99501-3572 OFMain: 907 279.1433 ALAS' Fax• 907 276 7542 �� www aogcc.alaska.gov sNED MAS 1 4 2 Trudi Hallett Operations Engineer .: o t Hilcorp Alaska, LLC d 1 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay St A-15RD2 Sundry Number: 315-276 Dear Ms. Hallett: 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, c/i _ Cathy . Foerster Chair DATED this 'day of May, 2015 Encl. RECEIVED STATE OF ALASKA MAY 0 6 2 15 ALASKA OIL AND GAS CONSERVATION COMMISSION 003 5 Ark,APPLICATION FOR SUNDRY APPROVALSor71-S 20 AACI5.280 1.Type of Request: Abandon❑ Plug for Redrill LI Perforate New Pod 0 Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations E] Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowr❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Gas Lift Completion 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 202-019 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20105-02 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93B Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay St/A-15RD2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 - McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depkh Jv1D(ft)! Total DepthTVD V D(ft): Effective Depth MD(ft): Effective De tj�T--VD(ft):>' Plugs(measured): Junk(measured): 45- 1b,02 1b,04 10,02 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Production 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Liner 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.2#/L-80 SuperMax 9,243 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker S-3 Packer&ZXP Packer 9,547'(TVD)7,950'(TVD)&12,197'(MD)9,740'(TVD) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development Li Service LI 14.Estimated Date for 15.Well Status after proposed work: In progress under approved Sundry#315-222 Commencing Operations: Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett(ahilcorp.com Printed Name Trudi Hallett Title Operations Engineer 11AitSignature Phone (907)777-8323 Date 5/6/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 7k Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance CIOther: )K 3 O a° /S, 6 alJ /- ( 570 - is--?..0 p .,• Spacing Exception Required? Yes CI No Subsequent Form Required: / ,_ y O u a/47Q / APPROVED BY _ Approved by: / 9(,,,4 COMMISSIONER THE COMMISSION Date: GIN �� � � RBDMS t\; MAY 1 1 2015 ® D i �J® Submn Form ane Form 10-403(Revised 10/2012) p o eI I Or I1�t t�Om tfie date of approval. Attachments in Duplicate Well Prognosis Well: A-15RD2 llikorp Alaska,LL Date:05/5/2015 Well Name: Monopod A-15RD2 API Number: 50-733-20105-02 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: April 20, 2015 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 202-019 First Call Engineer: Trudi Hallett (907) 777-8323 (907) 301-6657 (M) Second Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Current Bottom Hole Pressure: 3,988 p'si..@ 14,069' (9,801.TVD) Based on a SI pressure survey on 7/31/2010 Maximum Expected BHP: 3,988 psi @ 14,000' MD(9,908 ND) No new perfs being added Max.Anticipated Surface Pressure: —0 p ' Based on ab ve and a hydrostatic fluid column of 4,197 psi. -.4283 psi/ft X 9,801 ND) yns— -2—/ Change to approved program: (Sundry#315-222) 0��°AZ, 'J/v `.- g—FD e_g'=' Due to a loss of injection support in the Northern Nose,Hilcorp has decided to utilize this wellbore for the Trading Bay Field producer to reduce the amount of drawdown on the Northern Nose of McArthur River Field. Hilcorp is proposing to complete uphole in the Trading Bay Field Subthrust in the Tyonek A-Sand. Tyonek A-Sands expected pressure^'2000 psi @ 4,654' MD(4,104'ND)(top proposed perf depth) Brief Well Summary A-15RD2 is an oil well on the Monopod Platform producing from the Northern Nose in McArthur River of Trading Bay Unit.✓ A-15RD2 is a long horizontal single completion penetrating benches 1 and 2 of the Hemlock. It is completed with a 4-1/2" combination blank and slotted liner from TD to base of G-Zone @ 12197' and a tapered string of 4-1/2" to 3-1/2" tbg running in 9-5/8" and 7" csg from 12380' to surface. Well was completed 3/28/02 as a Hemlock gas lift producer and then converted to ESP in February 2014. The ESP in the well failed on April 11th, 2015 and this workover is to replace the ESP equipment. Last Casing Test:02-03-2014 at 12,236'to 1,500 psig and charted for 30 minutes Brief Well Work Procedure 1. MIRU Monopod Platform Rig#56. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to punch tbg. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. POOH• RIH w/scraper o w/ /2"6,200production string. I /sy /5,...�� • RIH and set retainer in 9-5/8"csg @+/-6,100'V —444 fr • RU and RIH w/logging tool to verify cement in the 9-5/8"casing. • PU and RIH with Perf gun assembly,correlate with e-line,perf according to approved final perforations.LD guns. • ::. - - - - • -- -- -- - • - -- • . 9,435'. PU new gaslift completion assembly with SSSV,GLM,and packer. RIH w/completion and set pkr @ +/-4,050'.Test to 1500 psi charting for 30 min. Well Prognosis Well: A-15RD2 Hilcora Alaska,LI) Date:05/5/2015 6. Test packer to 1500 psi chart for 30 min. 7. Hang off well. 8. ND BOP, NU wellhead and test. 9. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current Well Head Diagram 4. BOP Drawing la SCHEMATIC Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: 02/05/2014 RKB to TBG Hanger=40' CASING DETAIL i F-11 SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' G , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 1 >114\ 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' L TUBING DETAIL 3-1/2" 9.2 L-80 Super Max Surface 9,243' 12-1/4" hole 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' to 8,464' 1 9-5/8" 2 at 8,157' MD s NO. Depth Item 4 1 9,243' Head Bolt On Discharge 2 9,245' Pump(x5)344067,67/5F4300 5 3 9,351' Pump Intake 4 9,370' Top of Motor(x2)470420,240/175/91 6 5 9,435' Bottom of ESP 6 9,547' Baker S-3 Pkr-5"pin x 4.5'VAM Top Pin Top of 4-1/2"liner with ZXP Liner Top 7 12,197' Packer w/4.000"seal bore from 12,226'- 12.241' 8 12,203' 3-1/2"80-40 Locator Seal Assy Perforation Data Top Zone Top(MD) Btm(MD) (ND) Btm(TVD) Amt Status Hem 12,410' 12,480' 9,793' 9,804' 70 Open 7 Hem 13,198' 13,330' 9,771' 9,766' 132 Open 8 �� Hem 14,234' 14,939' 9,887' 10,005' 705 Open 7" liner cemented at 12,380' MD/9787'TVD,76 deg hole e,,, 4-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) A-15RD2, ,620'MD TP... _ \A-15RD2L1 \ •-15RD2,Start=12,700'..MD ... 730'_�QD TD A-15RD2L A-15RD2L1,)tart=13,406'MD --M- Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 03-06-14 • 111 ' PROPOSED Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: Future RKB to TBG Hanger=40' CASING DETAIL SIZE wr GRADE CONN TOP BOTTOM 1 13-3/8" 61 K-55 BTC 36.9' 1073' 2 9-5/8" 47 L-80 BTC 36.9' 8157' 3 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' L iti4 , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' s ER'' 6 / 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' et -7 _ %AV 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' 5 TUBING DETAIL ="11.111311110.18 3-1/2" 9.2 L-80 SuperMax 36.9 ±4,070' I4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' L , NO. Depth Item ---► .9 1 ±300' SSSV 12-1/4" hole 9-5/8" 2 ±2,100' GLM at 8157 MD 3 ±2,815' GLM-Orifice , t0 8,464' 4 ±4,030' Chem Injection Mandrel 5 ±4,050' Packer 6 ±4,060' X Nipple 7 ±4,070' WLEG (PI t 8 ...tiff/81r" CI BP VL CO I 9 12,197' Top of 4-1/2"liner with ZXP Liner Top Packer w/ 4.000"seal bore from 12,226'-12.241' Suspected Hole in 7" 10 12,203' 3-1/2"80-40 Locator Seal Assy csg b/t 10,089'to Perforation Data 10,099' Top Btm Btm Zone (MD) (MD) Top(ND) (ND) Amt Status 7 AZN 25A ±4,654' ±5,100' ±4,104' ±4,460' 446' Future Hem 12,410' 12,480' 9,793' 9,804' 70 Open 9 .10 Hem 13,198' 13,330' 9,771' 9,766' 132 Open zillyli .\ Hem 14,234' 14,939' 9,887' 10,005' 705 Open 7" liner cemented at 12,380' MD/9787'TVD,76 deg hole angle 4-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) -A..-1512..D.......2...,..13..,620'MD TD A-15RD2L1 -15RD2,Start=12,700'..MD • • 13,730'MD TD • IP- A-15RD2L2 A-15RD2L1,Start=13,406'MD - I-I - II- -•--- 1 Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.64*tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(TVD)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 05/01/15 Nionopod Platform A-15RD2 Proposed Hifr .,gy urp m,ILIA: 05/05/2015 Monopod Tubing hanger,CIW-DCB-FBB, A-15RD2 11 X 3'A EUE lift and 31/2 IBT susp, 13 3/8 X 9 5/8 X 3'/2 w/3"type H BPV profile,2-'''A" continuous control lines BHTA,Bowen,3 1/8 5M X 3.5 Bowen top ....... IM ., +$NE Valve,Swab,WKM-M, p. 0 0 31/85MFE,HWO, &RA(o 4) DD trim 040 ,1111.111 I•I +MAW Valve,Wing,SSV,WKM-M, - 3 1/8 5M FE,w/Omni 15" '( O operator,EE trim Valve,Master,WKM-M, 'e'�� •' 3 1/8 5M FE,HWO, • 0 0 DD trim an(� 0 Opo Adapter,CIW-FBB,11"5M FE X to! iii 31/85Mstddtop,w/%npt control line exits,6 1/4"seal x•1I '■� •' pocket Tubing head,CIW-DCB, _.,1 I' 13 5/8 3M X 11 5M,w/2- lei — ` IIS 2 1/16 SM SSO, ' X-bottom prep ., `I o E 9IlI..11: . o I0,A... Valve,WKM-M, 0 0 2 1/16 5M FE,HWO,AA ui I nI ta Casing spool, OCT-C22-BG, �� 13 5/8 3M X 13 5/8 3M,w/ ''' - 'I fow 0 Valve,CIW-F,2"LPO 2-2" LPO �omm,t�%o,�i.i:, 3M,HWO,AA 9 5/8 casing hung off in this spool,C-22 slips "' "' III Casing head, Shaffer KD, '' 135/83MX133/8SOW, l ���- w/2-2" LPO 1 rHi�i��� -i.1 Valve,ball,CIW,2"line No slips or packoff in pipe head, removed during 2002 redrill Monopod Platform 2013 BOP Stack 03/12/2013 Hilenrp,Alaska.EU.I.1 Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe 1111(111111211I • IurliTiTiT 'LsTiit u 3.74' Shaffer 13 5/8 SM III III III Iil 111 26.25' Shaffer UR 2 7/8-5 Variables 2.50' 13535©M Blind IIPI�1'I� 1.1 1 I. ,I 1.76 1 - 11 Mud Cross I' I I. I 1: '135/85MFEXFE w/31/85MEFO w/2 1/16 5M Choke and Kill valves w/Unibolt end connections for lines 2 83' Dual Cameron Flex rams I11i1. .1 I A'. .70' 4J14Jr11 V Drill deck 14.20" UOCD 1911 Riser 14.20' 13 5/8 5M FEX135/85M FE Ill III III II' 1 11101 II 1 li Spacer spool 1-5' 13 5/8 5M FE X 113M II'. 111 111111 11' Wellhead @ 15.00' Bettis, Patricia K (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Thursday, May 07, 2015 1:02 PM To: Roby, David S (DOA) Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA); Reid Edwards;James Young Subject: RE: Sundry application for Trading Bay St A-15RD2 (PTD202-019) Hi Dave, Please see comments in red below. I have also CC'd the Reservoir Engineers for Trading Bay Field and McArthur River Field in case you have further questions or need add'I information. Thanks- Treat i. Trudi Hallett I Operations Engineer Cook Inlet Offshore Asset Team Hilcorp Alaska,LLC Hilcorp A Company Built on Energy thallett(aThilcorp.com 0: 907.777.8323 C: 907.301.6657 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Thursday, May 07, 2015 12:06 PM To: Trudi Hallett Cc: Bettis, Patricia K (DOA); Schwartz, Guy L(DOA) Subject: Sundry application for Trading Bay St A-15RD2 (PTD202-019) Trudi, I'm reviewing the sundry application for the subject well for potential impacts on ultimate recovery and I have a couple of questions: 1) It appears the intent of this sundry is to isolate the lower perfs,which are in the McArthur River Field, by means of a retainer/CIBP and recomplete the well up hole in the Trading Bay Field. Is this correct? Yes,this is correct. 2) The well is currently producing at a couple hundred barrels of oil per day with a low GOR and a water cut about 95%. If the lower perfs are isolated will another well be capable of recovering the remaining reserves that would be left behind at this well's location? Yes—King Salmon, K-13 will be able to recover the reserves on the Northern Nose. 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 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 Dave Roby at(907)793-1232 or dave.roby@alaska.gov. 2 Bettis, Patricia K (DOA) From: Roby, David S (DOA) Sent: Thursday, May 07, 2015 12:06 PM To: thallett@hilcorp.com Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: Sundry application for Trading Bay St A-15RD2 (PTD202-019) Trudi, I'm reviewing the sundry application for the subject well for potential impacts on ultimate recovery and I have a couple of questions: 1) It appears the intent of this sundry is to isolate the lower perfs, which are in the McArthur River Field, by means of a retainer/CIBP and recomplete the well up hole in the Trading Bay Field. Is this correct? 2) The well is currently producing at a couple hundred barrels of oil per day with a low GOR and a water cut about 95%. If the lower perfs are isolated will another well be capable of recovering the remaining reserves that would be left behind at this well's location? 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 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 Dave Roby at(907)793-1232 or dave.roby@alaska.gov. 1 .,„..., ,ff•;:in.1.1... c :� ��. ;:.;11:.11.. ___,.=___ ,i, _ -'''''''''.. i.f.,,,,,....._,____:,,,_,,:i.: i !al:'1.: TA "'_ ,. -■ago rim:; fi �� ,,,,,„,,,,„ : ...i ' '..:::;:::.----.-.'-:-'-'---.7''--'''' ,.. lill'i...,':.::::-_EIEL.'4.k.,:,,,,,1910-;:s,.. v NM 5 i „......... , 1.) J .;/ kk y 1:::" 4W j--•ae.ra. 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EIMM r .(1l1... t g ...�® _ Immammmill 1 .,,:::. immium ,,,i.........,..mimi , MIMEO . 1E11111 1;t::::::•-11 MIN mo s, ■■■■■i■ •::;1■■■■ . .•_ er=g i :',,,,,,,,I....,,,..,.1......i.„..1 � , _ 4950 - � ��� - ��� :: ,< :., . ��� .....;!.....p..E..,..,...„..i...i.I..........„..i.....„...I,i.:....„....:...,....IF..IILiIII.,..„,,,t=L1._;.,7_,!1,1,,,=__•!7_,i_,_=_________72..__,,,„;,„,!„-i:_____L_._II,___!_;g.,,,:.,,.,__:„......I...„Ii,„:1,,:.I.,,.......,1..,1:IIi.•1•-1.,.:Ii.i.„..-,,.........!..„---,.;!.,.,..!.-II.,!,I.III'....II!IiIII:-•I:IIII,.,,III!.-1.:!!II : : - �� 1.111111.. -yam — #$'_ • - _ c, _ter- � — • •�$ •- -:. 1 — 5000E } h A •. - I 1 111111: i `` - s . a •IP:.$ m,„„;,,% ,,, . i at :: _ ., I 5050 �:r' I - R1 T =� 1 �t Giiiik I ill I �� * ' iIVIII = t4::•::. n t • ' _- WittitilbiW } r L -. -.� ..t _ 4--- . i �ir� n..,n _ pyii r 5100 • _ —i x:;"' 1' _ :::::.4:-A.:,.. ) 1 Itet 1 -r- �� •: •--, f t ' _ I . 5150 • • • = i • • T • `Schwartz, Guy L (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Thursday, May 07, 2015 1:43 PM To: Schwartz, Guy L(DOA) Subject: RE: MASP for new perfs (A-15RD2 PTD 202-019) Guy, Per your request, a worst case calculation yields the following assuming we hit gas. Max expected BHP 2000 psi at Top perf TVD 4104. Using 0.1 psi/ft.gradient to 4104 TVD yields 410 psi. Revised Max Anticipated Surface pressure is therefore 2000-410 =1590 PSI Thanks- Tru, U From: Schwartz, Guy L(DOA) [mailto:guy.schwartz©alaska.gov] Sent: Thursday, May 07, 2015 1:33 PM To: Trudi Hallett Subject: MASP for new pers (A-15RD2 PTD 202-019) Trudi, Can you recalculate a MASP based on gas gradient/BHP from the new perf interval from 4650-5100ft. Send by email reply. 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). 1 ti OF Ty 4,P* I//77 vA THE STATE Alaska Oil and Gas ofLASI�;A Conservation Commission A tis tz 333 west Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main. 907.279.1433 OF ALA€' Fax: 907 276 7542 www.aogcc alaska.gov SCANNED ;. , , Trudi Hallett Operations Engineer v 0 I Hilcorp Alaska, LLC D� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay St A -15RD2 Sundry Number: 315-222 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this / day of April, 2015 Encl. , RECEIVED STATE OF ALASKA APR 13 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A0000 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill El Perforate New Pod❑ Repair Well ErC.l Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pub Tubing p Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Replace ESP 0 2.Operator Name: 4.Current Wel Class: 5.Permit to DriN Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 202-019 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20105-02 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay St/A-15RD2' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MDp(ft): Total Dept TVD(ft): ''1i..3 EffectiveeDepth MD(ft): Effective Depth TVV+,D�(ft): Plugs(measured): Junk(measured): 1 0 2 `/1 i1 9 •�-00;5,042— JO,023. N/A N/A Casing Length Size MD TVD Burst Collapse Structural - Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Production 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Liner 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.2#/L-80 SuperMax 9,243 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker S-3 Packer&ZXP Packer 9,547'(ND)7,950'(ND)&12,197'(MD)9,740'(ND) 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic❑ Development 2• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/20/2015 Oil I] • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thalletta.hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature kikatija—Chtti (907)777-8323 Date 4/13/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J/ 315 -222 Plug Integrity ❑ BOP Test I{7 Mechanical Integrity Test ❑ Location Clearance Other: , riP �.es/- (ñ1Ps" ) / Spacing Exception Required? Yes ❑ No Subsequent Form Required: /t) -- Y Cy APPROVED BY Approved by: 92_,64,-/-6,‘...._ COMMISSIONER THE COMMISSION Date: 4-/7-/s 9K yl�ct.// * t/716(47----- , / '-/3' Submit Form and Form 10-403 evised 10/2012) efii6ifNisAtyren I for 12 months from the date of appro I. Attachments in Duplicate RBDMSI k APR 10 2015 Well Prognosis Well: A-15RD2 ffilcon)Alaska,LL Date:04/13/2015 Well Name: Monopod A-15RD2 API Number: 50-733-20105-02 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: April 20, 2015 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 202-019 First Call Engineer: Trudi Hallett (907) 777-8323 Second Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) AFE Number: Current Bottom Hole Pressure: 3,988 psi @ 14,069'(9,801 TVD)Based on a SI pressure survey on 7/31/2010 Maximum Expected BHP: 3,988 psi @ 14,000' MD(9,908 ND) No new perfs being added Max.Anticipated Surface Pressure:nn ^'0 psi (Based on above,and a hydrostatic fluid column of 4,197 psi.-.4283 N ) psi/ft X 9,801 D) Yr Aft d re-012,-;-.4" c._pp Ari Fa._ Z_co 44-c- L�.cc e)Cit)(i4 Brief Well Summary -4 -715- A-15RD2 is an oil well on the Monopod Platform producing from the Northern Nose in McArthur River of Trading Bay Unit. A-15RD2 is a long horizontal single completion penetrating benches 1 and 2 of the Hemlock. It is completed with a 4-1/2" combination blank and slotted liner from TD to base of G-Zone @ 12197' and a tapered string of 4-1/2" to 3-1/2" tbg running in 9-5/8" and 7"csg from 12380'to surface. Well was completed 3/28/02 as a Hemlock gas lift producer and then converted to ESP in February 2014. The ESP in the well failed on April 11th, 2015 and this workover is to replace the ESP equipment. Last Casing Test:02-03-2014 at 12,236'to 1,500 psig and charted for 30 minutes Brief Well Work Procedure 1. MIRU Monopod Platform Rig#56. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to punch tbg. 30cp es- 3. ND Wellhead, NU BOP and test to 250 psi low 1;03-5 i high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. POOH w/ESP pump on 3-1/2" production string. 5. PU new ESP assembly on 3-1/2" Production Tubing and RIH tubing setting the bottom of the ESP at(+/-) 9,435'. 6. Hang off well. 7. ND BOP, NU wellhead and test. 8. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current Well Head Diagram 4. BOP Drawing II SCHEMATIC Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: 02/05/2014 RKB to TBG Hanger=40' CASING DETAIL SIZE w-r GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' A , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' A _ TUBING DETAIL JP' 3-1/2" 9.2 L-80 Super Max Surface 9,243' 12-1/4"hole 4-1/2" 12.6 IBT Scab Liner 9,547 12,203' to 8,464' 1 mina, 9-5/8" z at 8,157' MD s NO. Depth Item 4 ill 1 9,243' Head Bolt On Discharge 2 9,245' Pump(x5)344067,67/SF4300 5 3 9,351' Pump Intake 4 9,370' Top of Motor(x2)470420,240/175/91 6 5 9,435' Bottom of ESP 6 9,547' Baker S-3 Pkr-5"pin x 4.5'VAM Top Pin Top of 4-1/2"liner with ZXP Liner Top 7 12,197' Packer w/4.000"seal bore from 12,226'- 12.241' 8 12,203' 3-1/2"80-40 Locator Seal Assy Perforation Data Top Zone Top(MD) Btm(MD) (ND) Btm(ND) Amt Status Hem 12,410' 12,480' 9,793' 9,804' 70 Open Hem 13,198' 13,330' 9,771' 9,766' 132 Open Hem 14,234' 14,939' 9,887' 10,005' 705 Open 7"liner cemented at 12,380' MD/9787'TVD,76 deg hole angle 1-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) A- 15RD2,13,620'MD TD • • • A-15RD2L1 -15RD2,Start=12,700'..MD • • :.13,730'MD TD A-15RD2L2 A-15RD2L1,Start=13,406'MD I-I - �I--- -.- 1 Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:ill 03-06-14 ' ll PROPOSED Monopod Platform Well #A-15RD2 Hilcorp Alaska, LLC Completed: FUTURE RKB to TBG Hanger=40' CASING DETAIL SIZE wT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' L , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' L TUBING DETAIL ---► 3-1/2" 9.2 L-80 Super Max Surface ±9,245' 12-1/4" hole 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' to 8,464' 9-5/8" at 8,157' MD NO. Depth Item 1 i 1 ±9,435' Bottom of ESP X X. 2 2 9,547' Baker S-3 Pkr-5"pin x 4.5'VAM Top Pin /� Top of 4-1/2"liner with ZXP Liner Top 3 12,197' Packer w/4.000"seal bore from 12,226'- 12.241' 4 12,203' 3-1/2"80-40 Locator Seal Assy Perforation Data Top Zone Top(MD) Btm(MD) (ND) Btm(ND) Amt Status Hem 12,410' 12,480' 9,793' 9,804' 70 _ Open ill . 3 Hem 13,198' 13,330' 9,771' 9,766' 132 Open 4 V.............. Hem 14,234' 14,939' 9,887' 10,005' 705 Open 7" liner cemented at 12,380' MD/9787'TVD, 76 deg hole angle F-5/03:Perfect liner 12,410'-480'(MD)/9,793'-9,804'(ND) ....A- 15RD2,13,620'MD TD A-15RD2L1 -15RD2,Start=12,700.:..MD' :13,730'MD TD A-15RD2L2 A-15RD2L1,Start=13,406'MD - N - - 11----71 Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 04/13/15 Monopod Platform A-15RD2 Hilrer:%lasku<ILIA, Monopod Tubing hanger,CIW-DCB- A-15RD2 ESP,11 X 4 Y.IBT lift and 133/8 X95/8 X4% susp,w/4"typeHBPV profile,5''/.EN,3-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,4 1/16 5M FE X 7"-5 Stub acme Bowen Union • M Jai Valve,swab,WKM-M, Cross,stdd,4 1/16 SM X 4 1/16 5M FE,HWO, - ' '� 3 1/8 5M X 2 1/16 5M T-24 Valve,wing,WKM-M, - - 2 1/16 SM FE,HWO, ° Valve,WKM-M,3 1/8 5M FE, . MOQ �o, jI w/MA-16 operator T-24 Valve,lower master, WKM-M,4 1/16 5M FE, Or O • HWO,T-24 �NMI r• ■ Adapter,CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 Y.EN neck,3-'/: npt continuous control line ports,BIW penetrator port 0-. —� a = Tubing head,CIW-DCB, III i� 111Valve,WKM-M,2 1/16 5M 13 5/8 3M X 11 5M,w/2- i9 FE,HWO,DD 2 1/16 SM SSO, kl X-bottom prep all Ii;\ II. iii Casing spool,OCT-C22-BG, • 135/83MX135/83M,w/ 111 2-2"LPO - Valve,CIW-F,2"LPO 4 9 5/8 casing hung off in thisI 3M,HWO,AA WU ( ]1-A spool,C-22 slips Casing head,Shaffer KD, 13 5/8 3M X 13 3/8 SOW, ,,, i I' Valve,ball,CIW,2"line w/2-2"LPO i e No slips or packoff in ��Nati ' p p head,removed during 2002 redrill Monopod Platform • ll 2013 BOP Stack 03/12/2013 rrclei.rp tht*La,.r.r.c. Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe i • 0 II'. t iii I I11 Ill 3.74' Shaffer 13 5/8 5M I I 1 dial I I 26.25' Shaffer L iiUR 27/8-5 Variables 2.50' — 13 5/8 SM Blind 1.76 191 d Cross r��. i I I I lair F.451- �� � ' °135/al 85MFEXFE w/31/85MEFO w/2 1/16 5M Choke and Kill valves w/Unibolt end connections for lines I11 IFI III.111 II, S/�SW Dual Cameron Flex rams 13 2.83' _..`... r 514 is - i I Ill I I 70' 11.11I! I Drill deck UOCD 1911 Riser 14.20' 135/85M FEX135/85M FE 111 III Iii.1 Imo'' I III : iii 111 Spacer spool 15' 135/85M FEX113M 11 1 1 111 III Wellhead @ 15.00' Im~ Project Well History File Cov~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. &. Q a. 0 J 9 Well History File Identifier Organizing (doli'" RESCAN V Color items: 0 Two-Sided 1111111111111111111 ~escan Needed 1111111111111111111 DIGITAL DATA OVERSIZED (Scannable) 0 Diskettes, No. 0 Maps: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: 0 Other, Norrype 0 Other items scannable by large scanner NOTES: OVERSIZED (Non-Scannable) / Logs of various kind~) 0 Other BY: BEVERLY ROBIN VINCENT SHERY~INOY ~.p ~"4~ If=-- X 30 =I~J.L +3.[',- = TOTAlPAGESJJL- DATEL//~ o¥ VVtP Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INOY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYLeWINOY Stage 1 PAGE COUNT FROM SCANNED FilE: l!L Production Scanning .\ ,J PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: ~ BEVERLY ROBIN VINCENT SHERYL MARIA WINOY DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: _YES_NO Isl _YES_NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINOY DATE: ISI (SC"'","O" COM""'" '"" """' """" ""'AC""""""" REOU'RED 0" '" ,"D'~DU"- eAOE ."" DUE W OU""'. GMm"-EDRC"'OR'",Ges) III 111I1II1111 !IIII ReScanned (i"'fivi"""1 p,'go 1^1",i.,I.,ttc"'i<mJ .<t.'""illg ""'"pill/od) 1111111111111111111 RESCANNEDBV: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Comments about this file: Quality Checked ("""", 1111111111111111111 121101Q2R"3NOTScaoood.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI-,,SON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well❑ Plug Perforations ❑ Perforate ❑ Other 9 Run ESP/Install Scab Liner Performed: Alter Casing❑ Pull Tubing I] Stimulate-Frac ❑ Q✓ 1N Waiver❑ Time Extension❑ le Change Approved Program❑ Operat.Shutdown Stimulate-Other ! 6,-"" Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Perm'` - rill Number: ti.'~ • Name: Hilcorp Alaska,LLC Development 9 Exploratory❑ ,a02-01��O2-'�/a3 ( 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: ,'"''` F. `" , Anchorage,AK 99503 50-733-20105-02 o 7.Property Designation(Lease Number): 8.Well Name and Number: MAR 0 6 2014 CI-Z) ADL0018731 , Trading Bay St/A-15RD2 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): v .,,� McArthur River Field/Hemlock Oil Pool C�+-A CC 11.Present Well Condition Summary: Total Depth measured . 15,042 feet Plugs measured N/A feet true vertical 9,797 feet Junk measured N/A feet Effective Depth measured ' 15,042 feet Packer measured 9,547&12197 feet true vertical 9,797 feet true vertical 7,950&9740 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 psi 1,540 psi Production 8,157' 9-5/8" 8,157' 6,848' 6,870 psi 4,760 psi Liner 4,370' 7" 12,380' 9,786' 8,160 psi 7,020 psi Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 psi 6,350 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED JUN 1 9 2014 . Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 Super Max 9,243'(MD) 7,704'(TVD) Baker S-3 Pkr 9,547'(MD)7,950'(TVD) Packers and SSSV(type,measured and true vertical depth) ZXP Pkr • 12,197'(MD)9,740'(TVD) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13,386'-14,960' RBDMSil MAY 1 3 2014 Treatment descriptions including volumes used and final pressure: Spotted 22 bbls of 9.95%HCL acid across slotted liner from 13,386'-14,960'. Pick up and chase acid with 180 bbls 3%KCL. 13. . Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 115 331 2305 1140 280 Subsequent to operation: 86 0 2680 96 80 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development9 Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: 0 Oil. 9 Gas 0 WDSPL❑ GSTOR 0 WINJ 0 WAG 0 GINJ❑ 3USP❑ 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: 3\3—lQ A-L\ Contact Ted Kramer Email tkramere..hilcorp.com Printed Name Ted Kramer 11 Title Sr.Operations Engineer Signature � C Phone (907)777-8420 Date 3/6/2014 -t � 6. /2_ 4y Form 10-404 Revised 10/2012 Submit Original Only II SCHEMATIC Monopod Platform Well #A-15RD2 Hilcora Alaska, LLC Completed: 02/05/2014 RKB to TBG Hanger=40' CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 Hyd 511 blank liner 12,197' 13198' Z , 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8"bull nosed hole finder joint on bottom of liner @ 15010' L TUBING DETAIL --► 3-1/2" 9.2 L-80 Super Max Surface 9,243' 12-1/4"hole 4-1/2" 12.6 IBT Scab Liner 9,547' 12,203' to 8,464' 1 - - 9-5/8" 2 at 8,157' MD 3 NO. Depth Item 4 1 9,243' Head Bolt On Discharge s 2 9,245' Pump(x5)344067,67/SF4300 3 9,351' Pump Intake 6 5 c, i - . 4 9,370' Top of Motor(x2)470420,240/175/91 5 9,435' Bottom of ESP 6 9,547' Baker S-3 Pkr-5"pin x 4.5'VAM Top Pin Top of 4-1/2"liner with ZXP Liner Top p A 7 12,197' Packer w/4.000"seal bore from 12,226'- e' c 6-5' 12.241' 8 12,203' 3-1/2"80-40 Locator Seal Assy 4-1 Perforation Data Top Zone Top(MD) Btm(MD) (ND) Btm(ND) Amt Status Hem 12,410' 12,480' 9,793' 9,804' 70 Open 1ZI Iq Ma Hem 13,198' 13,330' 9,771' 9,766' 132 Open NIIIIIIL111 Hem 14,234' 14,939' 9,887' 10,005' 705 Open 7" liner cemented at 12,380' MD/9787'TVD, 76 deg hole angle ♦-5/03:Perfed liner 12,410'-480'(MD)/9,793'-9,804'(ND) A-15RD2,13,620'MD TD • D2L1 .... i2 � ......... .13,730'MD TD 15RD2,Start=12,700'..MD '� .2/2- -CIL' A-15RD2L1,Start=13,406'MD - II 3 A_15RD2L2 Slotted Liner at Near-Horizontal in HB-1&2/ TD=15,042' MD 4-1/2"L-80,11.6#tbg with 2-1/2"x 1/8"slots,16 slots/ft 10,023' TVD 13,198'-13,330'(MD)/9,771'-9,776;(ND)and 14,234'-14,939'(MD)/9,877'-9,887'(ND) rest is blank liner Revised by:JLL 03-06-14 Hilcorp Alaska, LLC HilcorpAlaska,LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 1/23/2014 2/5/2014 Daily Operations: 01/23/14-Thursday • Rigging up. 01/24/14-Friday Rigging up. 01/25/14-Saturday N/U BOPE and associated equipment.Pull BPV and set TWC. Rig up BOP test Equipment.Test BOP's 250 pis low/2500 psi high.Test BOP to both 5" and 3 1/2"pipe size.VBR's to 5"and 3 1/2".Test Annular to 3 1/2"pipe size.Witness of test waived by Jim Regg,AOGCC.Rig down test equipment. Prepare to pull hanger.Pick up to pull hanger.Original pick up wt 163k.Hanger moving at 160k/.Weight fell off to 155k.Move pipe+/-3'.Weight started climbing.Pick up to 185k.No movement.Pick up to 190k.Pipe moved+/-1'.Staged up to 240k hook load.Pipe moved+/-4'.Total movement +/-7'.Continued to work pipe until string came free.Pick up wt 165k.Hole taking 35 bbls/hr.Pull hanger to rig floor.Rig up to lay down tubing.Today 3%Brine fluid loss to well 0 bbls-Total 3%Brine fluid loss to well 0 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 0 bbls-Total LCM loss to well 0 bbls-Total Ditch Magnet Metal recovery 0 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 0 lbs. 01/26/14-Sunday Rig up power tongs and 4 1/2"tubing handling equipment. PJSM on laying down completion.Lay down Tubing Hanger.POOH laying down 4 1/2" tubing SSSV and GLM's from Joint 249 to Joint 170.Continue to POOH laying down 4 1/2"tubing from Joint 170 to 4 1/2"x 3 1/2"XO.4 1/2"tubing below lower 4 1/2"gas lift mandrel plugged.Observed gas below perforated joint.Hot tapped and bled gas off remaining 4 1/2"tubing.Crossover plugged.Change over to 3 1/2"handling equipment.POOH laying down 3 1/2"tubing.1st 3 joints of 3 1/2"plugged solid.Remaining 3 1/2"tubing has severely restricted ID due to scale build up.Continued pulling and hot tapping as required.Tubing still plugged at several intervals.Today 3% Brine fluid loss to well 392 bbls-Total 3%Brine fluid loss to well 392 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 0 bbls-Total LCM loss to well 0 bbls-Total Ditch Magnet Metal recovery 0 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 0 lbs. 01/27/14-Monday Continue to L/D 3 1/2"tubing hot tapping each joint. Service Rig. Finish Laying down 3 1/2"tubing and jewelry.Rig down and clean tools. Scrub rig floor and deck areas.Slip and cut drill line.Set wear bushing. Pick up BHA- 6"mill,7"scraper,4 3/4"boot basket x 2,Bit sub,pump out sub,x-over, 4"H90 drill pipe. Pick up 9 5/8"BHA-9 5/8"scraper,7"boot basket x 2,bit sub,6 1/4"Bowen Lub Bumper sub,6 1/4"Bowen Oil jar,9 ea.6 1/4" drill collars.Circulate hole.EOT at 8,024'.&liner top at 8,010'.Prepare to RIH.RIH with 5"drill pipe.Today 3%Brine fluid loss to well 102 bbls-Total 3%Brine fluid loss to well 494 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 0 bbls-Total LCM loss to well 0 bbls-Total Ditch Magnet Metal recovery 0 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 0 lbs. 01/28/14-Tuesday Continue to TIH from 9,069'to 9,910',encounter set down @ 9,910'.Work pipe down to 9,922'.PU Kelly and wash and ream down to 10,026'. 10 BPM w/890 psi,30 RPM @ 13K to 15K torque.Wash Kelly to surface. Wash and ream down again with same parameters. At 10,016'lost 600 psi pump pressure and 30K string weight.Circulate shakers clean.Blow down and set back Kelly.Lay down 2 singles. TOH from stand 57 to 6 1/2"DC's. Stand back 1 std DC's.POOH with 2nd stand and discovered that the pin end on#5 DC pulled out of Box end of#4 DC in the hole.Pin end is pitted and eroded. Lay down all 6 1/2"DC's. Service rig.Clean and organize rig while waiting on Grapple.Pull mouse hole and remove mouse hole extension. Grapple on Location @ 14:30. MU BOT 8 1/8"Overshot with 6 1/2"Grapple.TIH to 5,620'.Estimated TOF @ 5,648'.PU Kelly.Break circulation.Single in hole on Kelly washing from 5,620'to 5,686'. Did not see TOF. Break out and set back Kelly.TIH on elevators from 5,686'chasing fish.Tag top of fish @7,831"-top of 7"liner-obtain parameters-puw 200k-sow 130k-rtw 15k/trq 10k-engage fish at 7,831'-set 20k down on fish to lock grapple.Pull fish free at 295k-circ at 8 bpm/460 psi out grapple at 7,831'-blow down and set back Kelly.LD single-POOH slow with fish. LD overshot-9 5/8"clean out assembly.POOH with 4 1/2"DP and 7"BHA. LD BHA-clean boot baskets.Clear floor. MU BHA#3-7"scraper with 6'mill.Today 3%Brine fluid loss to well 854 bbls-Total 3%Brine fluid loss to well 1348bb1s-Today SSP loss to well 0 bbls-Total SSP loss to well 0 bbls-Total Ditch Magnet Metal recovery 0 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 0 lbs. Hilcorp Alaska, LLC HiIcorpAIaeka,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 1/23/2014 2/5/2014 Daily Operations: 01/29/14-Wednesday Continue to TIH on 4"DP from 221'to 6,353'checking connection torque on each joint. Load strap and tally new 6-1/2"DC's. PU and TIH with(9)6- 1/2"DC's on top of 4"DP. POOH standing back 6-1/2"DC's. Continue to TIH 6,353'to 8,010'.Top of 7"liner.Continue to TIH to 12,131'. Tag TOL @ 12,197'.Stand Back 1 Stand. MU Kelly.Fill pipe(40 bbls to fill).Pump and spot 40 bbls sized salt pill in annulus above the 4-1/2"liner.Circulate across top of hole with charge pump for 1 hr monitoring losses.Losses slowed from 80 BPH static to 35-40 BPH static.Pump 20 bbls High Vis sweep to surface with 10% increase in debris @ shakers.Traces of scale mostly paraffin.Had 720 Units gas @ bottoms up strokes.Recovered all 20 bbls of sweep.Break off,blow down and set back Kelly.Monitor well with 16 BPH static loss.TOH from 12,180'to surface.LD BHA#3-empty boot baskets- no metal recovery.Service rig.Monitor well-32 bph static loss.MU 7"RTTS. RIH with 7"RTTS to 7"TOL at 8,010'.Fill hole with 13 bbls. Continue RIH.Today 3%Brine fluid loss to well 965 bbls-Total 3%Brine fluid loss to well 1459 bbls-Today SSP loss to well 40 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 0 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 0 lbs. 01/30/14-Thursday Continue to TIH from 8,010'to 12,190'.PU single and Tag TOL @ 12,197"PUH to 12,190'.Up Wt 240K,Dn Wt 140K. Set RTTS.Rig Up circulating hose to annulus.RU Chart to MP#1 in Pump Room. Attempt to test 7"and 9-5/8"csg.No Test.Stage out of the hole and test csg in 500'intervals from 12,190'to 9,836'with no success. Suspect 7"x 9-5/8"liner lap leaking.POOH to 28'below TOL @ 8,038'.Test 7"Liner top and 9-5/8"casing to 1650 psi for 30 min.Chart same.Continue to stage in hole in 500'intervals looking for top of leak to 10,404'. Stage out of hole in 100' interval to 10,026' test passed. Stage in hole in 30'intervals. Switch to mud pump#2. Located leak between 10,089'and 10,099'. Test passed at 10,089-test failed at 10,099'. POOH with RTTS.Continue POOH and LD RTTS.Pull wear bushing. PU test tools-2-7/8"test jt. RU test pump,set test plug,fill stack.Close LPR to work on BOPE. Change out HCR choke valve.Start replacing internal gate slide in#4 choke manifold valve. Test#1 LPR-#2 VPR,HCR choke, manual kill-#3 annular to 250 psi/2500 psi.Today 3%Brine fluid loss to well 459 bbls-Total 3%Brine fluid loss to well 2303 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. 01/31/14-Friday Set wear bushing.Rig down test equipment.PU 2-7/8"Handling Equipment and Power Tongs.PU BHA#4 as follows:PU and run in hole with 92 jts 2- 7/8"SLH-90 Drill Pipe,Strap,Tally and Drift in V-Door.MU XO.Rig down tongs.C/O to 4"DP handling equipment.PU remaining BHA Components:4- 3/4"Lub Bumper Sub,Oil Jar,(6)4-3/4"DC's,Accel Jar,XO,(65)stds 4"HT-38 DP,XO to 5"DP. Fill pipe and hole-25 bbls.Continue RIH with BHA# 4,obtain parameters-puw 223k-sow 135k-3 bpm/350 psi-no problem entering 4-1/2"liner-washing from TOL 12,197'to 13,431'-3 bpm/500 psi 22 bph loss-increase pump rate to 4 bph/900 psi with 23 bph loss-returns to shakers.Continue washing from 13,431'to 14,548'at 4 bpm/900 psi with 23 bph loss-as deeper in hole pressures and losses increased from 900 psi to 1100 psi and losses from 23 to 25 bph-as hard band entered the liner pressures and losses increased to 1200 psi and 30 bph-reduced pump rate to 3.5 bpm-pressures back down 900/1000 psi loss rate at 35 bph.Today 3%Brine fluid loss to well 202 bbls-Total 3%Brine fluid loss to well 2505 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. 02/01/14-Saturday Continue to wash through 4-1/2"liner from 14,800'to 14,960'@ 4 BPM with 970psi.3 BPM 640 PSI Up Wt 275K,Dn Wt 140K.Circulate 185 BBL drill string volume while reciprocating pipe.5 BPM with 1600 psi.Pump 22 bbls 9.95%HCL Acid.Chase and spot acid in 4-1/2"liner with 180 bbls 3 KCL Brine. Blow down and set back Kelly.POOH laying down 5"DP from 14,960'to 13,386'(49 jts).POOH standing back 5"DP from 13,386'to 12,138'. Circulate bottoms up with no gas or debris at shaker.TOH with 5"DP to 9,200'. C/O to 4"handling equipment.Continue to POOH with 65 stds 4"DP. LD BHA-stand back 2 stds DC-clear floor Weatherford equip-change elevators. MU TIW-45 bph loss. POOH-LD 2-7/8"DP. RD power tongs. Clean floor prep for BOPE test. Remove wear bushing.PU test tools.MU 5"test jt-set test plug-RU test equip. Test BOPE as per HAK-Kuukpik- AOGCC procedures-250 psi low/2500 psi high for 5 mins each test-Annular and upper VRB with 5"-Dart-TIW valve-Kill HCR-manual vlvs-outter Kill Demco-choke valves#1,3,5,7,16-Manual choke-Koomey drawdown.Witness of test waived by AOGCC Supervisor Jim Regg 2/1/14. Today 3% Brine fluid loss to well 543 bbls-Total 3%Brine fluid loss to well 3048 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LEA; Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-15RD2 50-733-20105-02 202-019 1/23/2014 2/5/2014 Daily Operations: 02/02/14-Sunday Continue to test BOPE to 250/2500 psi.Test to 5"and 2-7/8"Pipe size with no failures. Perform Accumulator Test.Rig down test equipment.Set Wear Bushing. Rig up E-Line.RIH w/Sondex 40 arm caliper to 11,983'. Log up @ 50 fpm from 11,983'to 7,950'WLM.End of Log.POOH and rig down E-Line. Hole in 7"casing @ 10,565',10,495',10,456', 10,386', 9,915'1 Corrosion from 9,915'to 9,550'. Good casing from 9,550'to Liner top @ DAP 8,010'. Wait on PKR,Seal Assy and 4-1/2"tubing.Clean and service rig areas. MU locator seal assembly -fill hole with 75 bbls KCL. RIH with locator w„,51. seal assembly on 4.5"tbg. MU Baker S-3 pkr, C-2 tie back sleeve,running tool,and xo.RIH with pkr on 4"DP. Today 3%Brine fluid loss to well 0 bbls -Total 3%Brine fluid loss to well 3048 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs- Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. 02/03/14-Monday Continue to TIH with Isolation PKR assy on 4"DP to 8,849'.X0 and TIH on 5'DP to 12,166'.PU 5'and 10'5"DP Pups for space out.MU Kelly.Break circulation,fill back side with kill line.Engage 4-1/2"Liner top @ 12,197'with seals. No go @ 12,236'(4.00 seal bore from 12,226'-12,241'below 4- 1/2"Liner top @ 12,197'). Drop Ball and wait 15 Min.Pump Ball on seat. Stage MP up to 1000 psi and take over with test pump to 4200 psi and set PKR with good Indication.Hold Pressure for 15 Min. Test top of PKR to 1500 psi.Test Good. Release running tool from PKR.TOH with PKR running tool.Lay down same.Pull wear bushing. Lay out,strap and tally 312 jts tubing.Rig up and spot ESP equipment.PU ESP equip-hang sheaves-MU ESP pump.Continue MU ESP pump. All sections of pump assembled.Test pump. Today 3%Brine fluid loss to well 212 bbls-Total 3%Brine fluid loss to well 3260 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. 02/04/14-Tuesday Run ESP in hole picking up 3-1/2"tbg.Running ESP cable,dual control line for Injection valves and securing with cannon clamps.Meg test every 600'. Continue RIH w/ESP completion t/4,180'.Meg Test and Test injection valve lines.Hole had not been filled for 26 hrs.Hole took 94 bbls to reach surface in ann.Continue RIH w/ESP completion to 4,988'.End of 1 st spool of electric cable.Install floor valve. Splice ESP cable and test on 2nd spool.Installing Canon clamps every other jt. Continue RIH with ESP equip test cable and lines every 30 jts.PJSM. Pump 50 bbls KCL into well. Continue RIH with ESP equip-installing Canon clamps every other jt. Did not see a bobble entering liner at 8,010'-test cable/lines 10 jts into liner. Ran total 277 jts 3-1/2"tbg. MU hgr with ESP penetrator and install BPV. Today 3%Brine fluid loss to well 162 bbls-Total 3%Brine fluid loss to well 3422 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. 02/05/14-Wednesday Make cable splice at penetrator on tbg hanger and meg same.Test injection lines for leaks at hanger connections.Attempt to plug umbilical cord into penetrator.Summit had the wrong plug on their umbilical cord.MU connectors on a extension cord to replace umbilical cord.Test cord and it tested good.Land hanger with 44k hanging.[Up wt 190k,Dn wt 61k).Test motor through umbilical cord.Good test.Run in LDS.Pull,break dn,and lay dn landing jt.Pack off hanger seals.Clear rig floor of completion running equip.Nipple down BOPs.Pull and lay down riser.Prep well head.Stage valves in cellar while breaking dn tree because it wouldn't fit through rotary table.Make up bottom flange off tree and test void to 5000 psi for 10 min. Lower down and nipple up all the valves off the tree-Pull BPV-set TWC-test tree 250/5000psi/10 min-prep to skid rig. Remove storm clamps- stairs.Prep to skid rig.Remove hand rails,pull back landings and support Beaver Slide with crane. Release well A-15RD2 to Production.Today 3% Brine fluid loss to well 153 bbls-Total 3%Brine fluid loss to well 3475 bbls-Today SSP loss to well 0 bbls-Total SSP loss to well 40 bbls-Total Ditch Magnet Metal recovery 17 lbs-Total boot basket metal recovery 0 lbs-Total metal recovered from well 17 lbs. Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Sunday, February 02,2014 5:25 PM To: Schwartz,Guy L(DOA); Ferguson,Victoria L(DOA) Subject A-15 Program Change- Bad Casing Sundry#313-641, PTD#202-063 Attachments: A-15RD2 Schematic W scab liner 2-2-14.doc Guy and Victoria, Hilcorp has encountered Bad Casing From 10,088 ft.dow to the top of the 4-1/2" liner at 12,197'. To remediate this, Hilcorp plans to run a seal assembly on 4-1/2"tubing and below an isolation packer which will be set at 9,500'(+/-). This will isolate the bad casing up past a point where we have achieved a good pressure test(10,089' up to surface to 1,650 psi for 30 min.) and a caliper log has confirmed good casing. We will set the ESP above this scab liner. Ted Kramer 985-867-0665 1 e e Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 16, 2006 ..r0\' ~ Steve McMains AOGCC 333 W. th Avenue, Ste. 100 Anchorage, Alaska 99501 ~!1 ", Re: Outstanding Sundries Dear Mr. McMains, We have conducted an internal audit of regulatory filings for 2003 and 2004. As a result, several projects were found to have outstanding sundries. We have researched the work and have prepared the sundries to close out the projects left uncompleted. The list of projects includes the following: 2003 Grayling, G-12RD3, Reperforate Grayling, G-24, Reperforate Monopod, A-15RD2, Perforate V Steelhead, M-01, Repair Casing Patch Steelhead, M-05, Perforate Swanson River, SCU 32-04, Reperforate (3 Sundries) Swanson River, SRU 12-15, Recomplete Swanson River, SRU 32A-33, Reperforate 2004 Happy Valley, HV-A02, Coil Tubing Clean Out In order to assure that we do not have any such gaps in the future, we have implemented a database to track all drilling related AOGCC filling requirements. Please contact me directly at 263-7657 if you have any questions about these filings. Sincerely, ~~.^~ý Timothy C. Brandenburg Drilling Manager Attachments Cc: Well Files TB:sk Union Oil Company of California I A Chevron Company http://www.chevron.com STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 202-019 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D ServiceD 6. API Number: 50-733-20105-02 7. KB Elevation (ft): 9. Well Name and Number: 101' above MSL A-15RD2 8. Property Designation: 10. Field/Pool(s): Monopod Platform Cook Inlet McArthur River Field/Hemlock and E 11. Present Well Condition Summary: Total Depth measured 15,042' feet Plugs (measured) n/a true vertical 9,794' feet Junk (measured) n/a Effective Depth measured 15,042' feet true vertical 9,794' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,073' 13-3/8" 1,073' 1,054' 3,090 1,540 Production 8,157' 9-5/8" 8,157' 6,848' 6,870 4,760 Liner 4,370' 7" 12,380' 9,786' 8,160 7,020 Liner 2,742' 4-1/2" 14,939' 9,805' 7,780 6,350 Perforation depth: Measured depth: Slotted liner @ 13,198-13,330'; 14,234-14,939' True Vertical depth: Slotted liner @ 9,801-9,799'; 9,791-9,801' Tubing: (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 7,926'; 3-1/2", 9.2#, N-80 @ 12,246' Packers and SSSV (type and measured depth) Baker 4-1/2" TRDP-1A SSSV @ 340'; ZXP liner top packer @ 12,197' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 490 2,309 1,802 1,080 135 Subsequent to operation: 434 1,584 1,898 1,040 120 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run ExploratoryD Development 0 Service D Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 GasD WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: 303-119 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature '7 - ~-é.%'~ C/ Phone 7-276-7600 Date 7~/-~- "" " .b.. ~ ¿;,-/ . 'n.... _. "" '-'MI1 1. , Form 10-404 Revised 04/2004 AFE 160592 ~ Submit Original Only RKB to TBG Hanger 40' t 12-1/4" hole to 8464' 9-5/8" at 8157' MD 2a ~ 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-80 11.6 Hyd 511 bhmk linerl2197' 13198' 4-1/2" 11.6 L-80 Hyd511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 11.6Hyd511 bhmkliner13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8" bull nosed hole finder joint on bottom of liner @ 15010' Tubing: 4-1/2" 12.6 N-80 BTC 40' 7926' 3-1/2" 9.2 N-80 BTC 7926' ]2246' 1. 2. 2a 5. 6 340' 7926' 11408' 12246 ' 12197" Baker 4-1/2" TRDP-IA SSSV (ID = 3.813") 4-1/2" x 3-1/2" crossover Baker 3-1/2" CMD sliding sleeve (49 deg hole) 3-1/2" tbg with 4.00" tubing seals Top of 4-1/2" liner with ZXP Liner top packer and with 4.000" seal bore from 12226' to 12241' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3- 1 /2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 valve and RK latch 3-1/2" SFO-2 GLM with R-2 orifice and RK latch 7" liner cemented at 12380' MD/ 9787' TVD, 76 deg hole Perforate HB-Ol12,410 to 12,480',6 SPF, 60 deg phasing 5/1/03 / 1 2 3 4 5 6 7 8 9 10 11 12 13 14 2085' 3753' 4892' 5780' 6451' 7027' 7604' 8156' 8750' 9310' 9866' 10426' 11046' 11613' 4-1/2" L-80, 11.6# tbg with 2-1/2" x 1/8" slots, ] 6 slots/ft 13198'-13330' and 14234'-14939', rest is blank liner ¡ \. ._.__._._._...L1 ------1 90 Deg belly at 12514' MD/9805' TVD MAX HOLE ANGLE = 96.380 (q) 13486' TD = 15042' MD/9794' TVD A-15RDPerforate050203 REVISED: 03/01/06 DRAWN BY: TAB ~ e e 4/30/03 PJSM. Check out and OK SWS Unit, Spot SWS Unit and skid rig 1 foot to south. Check out Schlumberger and Welltec tools as per joint SWS and Welltec check list. Nabors tool pusher start up and check out draw works/rig. Start rig up 5" lubricator. PT 5" lubricator to 2500 psig. Bleed off and installed night cap and chained back lubricator on rig floor. 5/1/03 PJSM. MU tools and first run perforating guns of 37. RIH 70psi WHP. Static tool wt. 560#. Communication test on tractor at 500' MD. Tools stop RIH at 12,050' MD. Check pick up wt. Log up to 11,450' MD for upper correlation log with CCL and Gamma 2 ft. low make adjustments. WHP 70 psig. RIH with tools to 12,050' MD static wt 1,874 drop off. Start tractor to tractor in well volts 800 amps 3.8 constant feed in wire line rate off 2,100 ft/hr. Tractor to 12,555' MD switch to DC power and start logging up. Pick up wt 3,650# log up to 11,750' MD 4 ft high make adjustments. RIH with tools to 12,070' MD. Pick up wt 3,600#. Start tractor to tractor in well Volts 800 amps 3.8 constant feed in 10 ft slack cable at rate of 2,400 ft/hr, 14:01 slow rate to 2,075 ft/hr to ck best rate. Return rate to 2,400 ft/hr. Tractor to 12,553' MD switch to DC power and start logging up. Log up to 12,220' MD 3 ft low make adjustments RIH with tools to 12,070' MD , tractor down to 12,562' MD. Pick up wt. 3,500# WHP 125 psig. Log up from 12,562' MD to stop depth of 12,436' CCL to top shot depth. Btm 12,480' MD, Fire guns. Loss wt of 300#. Fire gun run #1 WHP 180 psig. POOH, check tractor communication and load test at 12,280' MD. Tractor functioned 800 volts 3.8 amps (ok). POOH with tools all guns fired. Redress tools PJSM, night crew MU tools and second run perforating guns of 37. RIH with tools, SOD' MD check tractor with communication test. RIH with CCL only. Tools stop 12,000' MD log up hole to 11,800' MD. RIH with wt, fall to 12,407' MD and log up to 12,100' MD check 7" liner correlation CCL tie-in. Log off 5 feet high. RIH with wt, fall to 12,446' MD pick up wt 3000# and log up to 11,947' MD again to check 7" liner correlation CCL tie-in. Pull up again through 7" Log correlated. RIH with wt, fall to 12,380' MD pick up slack, tractor down to 12,441' MD to position tools. Logging up to shot depth CCL 12,405.4' MD for a top shot of 12,410' MD. WHP 140 psig. Guns fired. Fire gun run #2 WHP 140 psig. POOH, all guns fired. LD tools, RD lubricator. 5/2/03 RD/MO. A-15RD, AFE 160592 morning report summary, CONFIDENTIAL: last revised 2/3/2006, Page 1. . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker. doc ¡q ~yJ ~oovt DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020190 Well Name/No. TRADING BAY ST TBU A-15RD2 Operator UNION OIL CO OF CALIFORNIA 5"0 Qá. '1 rc.b ), ~ '-{ ¡ API No. 50-733-20105-02-00 MD 13620 -- TVD 9783 /' Completion Date 3/30/2002 ./ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Med/Frmt Number ) Name Received Comments C Vw905 IJQg Rpt ¡.,. 11360 13280 Open 5/6/2002 Formation Evaluation and Survey 25 Blu 1 11360 13280 Open 5/6/2002 Case 7/24/2002 Also includes Report for 201-189,202-048 & 202- 063. Report is located in Well History f~:. 2?2-063. 2 Blu 10430 13613 Case 7/24f2002 Formation Log 11400 12381 9/13/2002 10430 13620 9/13/2002 ) 11360 13280 9f13/2002 10430 13618 9/13/2002 9/13/2002 10430 13369 9f13/2002 Vision Density Neutron 10430 12632 9/13/2002 Impulse Resistivity Log ED C Las (11758 . r ED C Las \117~8 ~~ ED C Las 1175,8 ~~ C Las 11758 X lED ~ . ED C Asc 117~8 ED C Pds 11758 ED C Pds 1758 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020190 Well Name/No. TRADING BAY ST TBU A-15RD2 Operator UNION OIL CO OF CALIFORNIA API No. 50-733-20105-02-00 MD 13620 TVD 9783 ADDITIONAL INFORMATION Well Cored? Y /6 Chips Received? ' Y,' N Completion Date 3/30f2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? &}N @N Formation Tops Analysis Received? -'14-1*- Comments: Compliance Reviewed By: ~ Date: ~ t1r ~- ) ) ~ ~ hi-fI CZr 1 (") o.s<~S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS if c/ IJ~ /r ~ 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: ' - - - Alter casing: Repair well: Plugging: Time extension: Stimulate: - - - - Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (OF or KB) Union Oil Company of California (Unocal) Development: ~ 101' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name - Stratigraphic: - PO BOX 196247 ANC, AK. !}.9519 Service: Trading Bay Field 4. Location of well at surface v-J"-J 8. Well numbeV 1616' FSL, 576' FEL, Sec. 4-T9N-R13W-SM A-15RD2 At top of productive interval 9. Permit number 1265' FSL, 1717' FWL, Sec. 10-T9N-R13W-SM 202-019 At effective depth 10. API number ../ 73' FSL, 1338' FWL, Sec. 10-T9N-R13W-SM 50-733-20105-02 At total depth 11. Field/Pool 73' FSL, 1338' FWL, Sec. 10-T9N-R13W-SM TBF, Hemlock and E pool 12. Present well condition summary 13,620 "/'- Total depth: measured feet Plugs (measured) None true vertical 9,983 feet Effective depth: measured 13,620 feet Junk (measured) None true vertical 9,783 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,073 13-3/8" 1200 sx 1,073 1,054 Intermediate Production 8,157 9-5/8" 1,700 sx 8,157 6,848 Liner 4,370 7" 1,700 sx 12,380 9,786 Perforation depth: measured see attached schematic true vertical Tubing (size, grade, and measured depth) 4-1/2" 12.6# 1-80 @ 12,700 ft Packers and SSSV (type and measured depth) ZXP Liner Top Packer @ 12,197' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: - - Well bore schematic Temperature survey 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: X Gas: Suspended: - - - Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: /...ç: ~ Title: WOl"kofl/t!/ h.re-., -- Date: y fi ý'~J 5T<!:o/t! Ty /~- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repre~Z:ive may witness3SC::O\>,,>\ ß C \>-\~c,. -\ 1V'\.\. '" '\ ~\)'f-\ Approval No. (c¡ Plug integrity- BOP Test Location clearance- REG - 3D3 -II Mechanical Integrity Test- Subsequent form required 10- ~C)'-\ t: I V I:: U APR 1 4 2003 Alaska Oil & Gas Cons. Commission ~ ~~ ,.. Anchorage 'I//~/ oJ Approved by order of the Commissioner ~ Commissioner Date Form 10-403 Rev 06f15/88 ORIGINAL ~l~~ lb¡)¡r tho SUBMIT IN TRIPLICATE WR 2 ~ 2WH:i ~ ,..-... RKB to TBG Hanger = 40' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-8011.6Hyd51IblanklinerI2197' 13198' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-8011.6Hyd51IblanklinerI3329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8" bull nosed hole finder joint on bottom ofliner@ 15010' Tubing: 4-1/2" 12.6 N-80 3-1/2" 9.2 N-80 BTC BTC 40' 7926' 7926' 12246' L1 ~ ~ JEWELRY DETAIL NO, Depth Item 1. 340' Baker 4-1/2" TROP-IA SSSV (10 = 3.813") 2. 7926' 4-1/2" x 3-1/2" crossover 2a 11408' Baker 3-1/2" CMO sliding sleeve (49 deg hole) 5. 12246' 3-1/2" tbg with 4.00" tubing seals 6 12197" Top of 4-1/2" liner with ZXP Liner top packer and with 4.000" seal bore from 12226' to 12241' Gas Lift Information I 2085' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 3753' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 4892' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 5780' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 6451' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 6 7027' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 7 7604' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 8 8156' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 8750' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 9310' 3-1/2" SFO-2 GLM with R-2 valve and RK latch II 9866' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 12 10426' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 13 11046' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 14 11613' 3-1/2" SFO-2 GLM with R-2 orifice and RK latch L1 t 12-1/4" hole to 8464' 9-~8" at 8157' MD 2a L1 7" liner cemented at 12380' MOl 9787' TVO, 76 deg hole Slotted Liner at Near-Horizontal in HB-1&2 4-1/2" L-80, 11.6# tbg with 2-1/2" x 1/8" slots, 16 slots/ft 13198'-13330' and 14234'-14939', rest is blank liner , \. ...-.-.....-...- ~\(J.~\o r<-~'\ ~/ \ . ,G - \~~~'-' ;)'-\ 90 Deg belly at 12514' MD/9805' TVD MAX HOLE ANGLE = 96.38° @ 13486' .'-'-..'-'-'-LJ TD = 15042' MD/9794'1VD .--.., ~. Proposed Perforations Top Btm Zone MD TVD MD TVD Amount HB-1 12,410' 9,792' 12,480' 9,802' 70' ~. Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocai.com ~. UNOCALfØ Debra A. Oudean Technologist September 12, 2002 DATA TRANSMITTAL To: From: Bren Mciver Debra A. Oudean Alaska Oil & Gas Unocal Alaska 333 W 7th Ave, #100 909 W. 9In Avenue AnchoraQe,AK99501-3539 Anchorage, AK 99501 Transmitting data as follows: Transmitting the following: Final Well Data. "\2~d. ~'W)...\ ~~dL9 co Trading Bay Field A-15RO, A-15RO"sT1, A-15RO ST1 L 1, A-15RO ST L 1 A CO Trading Bay Unit G-12RO 3- ClOCl<J.5S ~ ðt9' D\ ~ -_u if- II?LS<t -. a ad - ~ k\ <6 ~ ¡ \ 7-~ \ ~ \ \ l-lv~ 60d-Olo3~ t\15ÇJ' ztìal'15 RECEIVED SEP 13 2002 A1I8ka OÐ , GIi Coni. ConniIeiCIn Aßdiot8þ ,-...., ^, l' '" Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950\ Tele: (907) 263-765\ Fax: (907) 263-7828 E-mail: hamsonb@unocal.com UNOCALi) Beverly Harrison Business Ventures Assistant July 23, 2002 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - Monopod Platform EPOCH FINAL WELL REPORT W/ FORMATION LOG 21NCH 12/6/2002 1074-12428 EPOCH FINAL WELL REPORT W/ FORMATION LOG 21NCH 12/6/2002 10430-13613 EPOCH FINAL WELL REPORT W/ FORMATION LOG 21NCH 12/6/2002 12700-13730 EPOCH FINAL WELL REPORT W/ FORMATION LOG 21NCH 12/6/2002 13245-15042 2.CJ-¡f'~ A-15RD M..-Ol<\ A-15RD ST1 Ì-O, -,:,'-/.1 A-15RD ST1L1 .Lo)...-oI.t3 A-15RDST1L1A R, f,.'.'. r r ~ \! F 0 ,. JUL 2.. 4 2002 . .. 'ommiSSlQ.O AlasKa LIB 1St oii;:, ",uí\::¡, \J . ~ñchorage Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Rece;ved 8& ~ I Date, ~ ---.. ~ .n r, \;;z .~ ~ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 276-7600 ~~ /77. UNOCAL8 Matt Frankforter Sr. Advising Geologist May 5, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Steve Davies Name Changes for A-15RDST1 A-15RDST1L1 A-15RDST1 L 1 DP Monopod Platform Dear Mr. Davies: The following table describes the name changes that have occurred between permitting and completion of the various well bores associated with the original A-15RD well. Permit # 202-019 202-048 202-063 API # 50-733-20105-02 50-733-20105-60 50-733-20105-61 Permit Name A-15RDST1 A-15RDST1L 1 A-15RDST1 L 1 DP ComDleted Name A-15RD2 A-15RD2L 1 A-15RD2L2 If you have any questions you can contact either myself at 263-7877 or Tim Billingsley- Drilling Engineer at 263-7659. a Frankforter Sr. Advising Geologist R F r r..~ I \ l E IJ"'. g"t.....\..L, Ii . V' .1\\/ ('¡ h ?1û?' ll,-~.¡ u v i,..\"v... AOGCC name change A-15RD2 et al.doc Alaska au & Gas Cons. CommiSSIDrI AnchoraQe ') Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Te1e: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unoca\.com ) UNOCALe Beverly Harrison Business Ventures Assistant May 3, 2002 To: AOGCC Lisa Weepie 333 7th Ave., Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL- Alaska I Offshore I Monopod Platform Wet Samples - Glass Vials A-15RD 11970'-12428' Box 1 of1 ;201 -/~9 j-O - 733 -.<0 10>- -(j I A-15RDSTl 10430'-11470' 11470'-12910' 12910'-13620' :~~ ~ ~g~ ;( d)' -1)J ~ /.\'0 -» , - -ZO Jor - òl. Box 3 of 3 .~ A-15RDSTILl 12700'-13430' Box 1 of 1 ^G À. ~ rj '-( 8 > ~ - 7 J .1- ^ C I () 1- - b <J *Total of 3 boxes for all samples. Samples for wells are intermixed. See label on box for details. SCANNED NOV 0 4 2004 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received BY:~ rJLJ Date:) ~ ~ ~ r"'( t./ ( " , I \: ,-.. ~, Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCAL8 Beverly Harrison Business Ventures Assistant May 2, 2002 To: Lisa I:æfpi:e W e.ep~ AOGCC 333 W. 7'h Ave, #100 Anchorage, AK 99501 DATA TRANSMITTAL - MONOPOD PLATFORM 1)d.-()4 tmLt' . LOG TYPE> '> ,,',' ,<.. .,T577 ,SCALE 'LôâD'ÃTE>Y~ ,. JNtERVAEH~' CO, :MEtl~ A-15RD fORMATION EVALUATION LOGS / SURVEYS 1/28/2002 I CD POWERPULSE / GR / VISION DENSITY NEUTRON / 2/5 ... COR / MD / COMPOSITE FIELD PRINT INCH 12/22/2001 1105-12378 1 B-Line POWERPULSE / GR / VISION DENSITY NEUTRON / 2/5 .- CDR / TVD / COMPOSITE FIELD PRINT INCH 12/22/2001 1105-12378 1 B-Line A-15RD2 FORMATION EVALUATION LOGS / SURVEYS 2/28/2002 I CD POWERPULSE / GR / MD / COMPOSITE F:ELD 2/5 PRINT INCH 2/3/2002 10400-13570 I B-Line POWERPULSE / IMPULSE / GR / VISION DESITY NEUTRON / MD / MAD PASS / COMPOSITE FIELD 2/5 PRINT INCH 2/3/2002 11360-13280 1 B-Line A-15RD2Ll ADN IMAGE DIPS 3/26/2002 12634-13725 I B-Line r6 ADN IMAGE DIPS 3/26/2002 12634-13725 1 CD .- FORMATION EV ALUA TION LOGS / SURVEYS 3/8/2002 1 CD VISION SERVICE 1 MD / COMPOSITE FIELD PRINT 12/6/2001 12700-13730 I B-Line .. VISION SERVICE / MD / MAD PASS / COMPOSITE .- FIELD PRINT 12/6/2001 12700-13730 I B-Line A-15RD2L2 AND IMAGE DIPS 1:120 3/11/2002 12630-15042 I B-Line AND IMAGE DIPS 1:120 3/11/2002 12630-15042 I CD FORMATION EVALUATION LOGS/SURVEYS 3/20/2002 I CD 2/5 VISION SERVICE / MD / COMPOSITE FIELD PRINT INCH 3/1/2002 12700-15042 I B-Line VISION SERVICE / MD / MAD PASS / COPPOSITE 2/5 FIELD PRINT INCH 3/1/2002 12700-15042 I B-Line ft} qtç ,OJ-/~C¡ \C9..o/'l )~-oIc3 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. IRece~~(bp~ I Dale ~ Alaska Oil & Gas Cons. CommÍSSÛ)n Anchorage ~ , ^ ~ ~ R .. v, .:::t:-~ ~: \ 1 '-J l>\ V~ ( (\J 0 .......... \) tn. I "- Uì ~ ~ <;;; ~ "'" U\ ~ ~." ;;;'\\ ~f1t VI ~ r ~ ~ ","::t~ ~ \) \ .t~ ",'? .~~. ~" \'~' t ~ L~ Ô ~ :;- \1. ~ t ~ ~... -Z- ~ tf ~ ""' V "'" v ~ ~ <;)'" ç:. , ¡: ~ ' ¡;; "" .. g '" Ò'o. '" I '¡t>..-ð it.. l... ~ ':--I Ì ,} '-- ! -I-- , ~ \} -:» ~ :-t~ .~. t. 1::.~. ~ t ",':- ~ d - \" )~ -ðz ~ . ~. .6..1. . . , R ,~.... w . " Ii' "- Y ~ - ;;¡ - ~";;- K.. N '" :';;- ~ ~ ' ~ . ~ - . D :¡, ~ LII ~ ....- .-}-;Lu -~" - '" ~ 'f. ... ~ '" § -4) If' ~ .,.-- --~_.s.",cno.u r t. ~. . ~ I ~ ~ ~, t ~~ ~ ~ ." ¡ ~ ~ cMiii ~'" ~, . '" ì ~I' ~ '" ~ '" N ~ f'J ~ ~ ",' ~ I ....,' ¡- '-.1-' î- . ~ w ~ J~}~ i f, "'" \\ \..t . ~ t' c.. t. ~ ~ ~} ~~< ~ I" ~' !<1 ~ ~ t N ~ ~ f' i' - t" -lJ~ r ~1 ~\~. ~, V\"«, ~ ~ \' . " "., ~~~ N I.: \ ~ C", ~, ~ ~ ' t~ ~ 9J ~ ~ ~ \ ~ '" ........ ..~ :"\ :¿ :f' ~ ~t:::> .p~~ )) r;t ~~R'~ ~4..~.( . ;' ~ t ~ -- - .0 ~ CJJ \:) I-~ -0 ~ . ~ Q . "];. ..~. --=Š;"" ~ ..¡: '" ~ 0'\ ..... ~ -+-. ~ ~ ~ , '0 ,. ,,:) -,... "'.. . '" Ç)-:r ~ ' (\ '"t- ,) g" .. - ~ ~, ~ ~ "" I' ~ .~ ~ 1 ~. ~~' t -r .... ~.... ~ 'J ....J ~~ },,4 ~ <, ~ 0 ~ "') ~ , ~'>< . '. t\) II) t\) N ........ ~i5 ~~ , () "- ~~ \' N ~ ~~N() \'-' I" . I I '" () " I vC>' fi" ~"'. tÞ W ~~...t\ ~, Unocal Corporation ""'""' P.O. Box 196247 Anchorage. AK 99501 Telephone (907) 263-7660 UNOCAL8 Dale Haines Drilling Manager April 25, 2002 Alaska Oil and Gas Conservation Commission 333 West th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Cammy Taylor Completion Reports (Form 407) A-15RD2 A-15RD2L 1 A-15RD2L2 Monopod Platform Dear Commissioner Taylor: Enclosed are three Completion Reports for A-15RD2, A-15RD2L 1 and A-15RD2L2. This well had many problems and sidetracks. The attachment to this letter explains the naming convention and the depths of each wellbore. If there are any questions, please contact Dale Haines at 263-7951 or Tim Billingsley-Drilling Engineer at 263-7659 or Matt Frankforter-Geologist at 263-7877. Sincerely, j)~ ~ ~~" Dale Haines Drilling Manager RECEIVED L PO ? ~) ?'In? , " . \. !.- '" ....V;,!.... Alaska Oil & Gas Cans. Commission Anchorage ,n AOGCC COY ltr A-15RD2 three comp reports.doc -., ~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 202-019 3. Address 8. API Number P. O. Box 196247, Anchorage, Ak 99519 !J¡; 50- 733-20105-02 4. Location of well at surface "'-':;;:;:,"'-;~',-:";~:;;"1 ¡ 9. Unit or Lease Name ; ..\Jj..;n c-, "JI'¡ .! \ - Trading Bay Field 1616' FSL, 576' FEL, Sec. 4, T9N, R13W, SM I - i'W"'~ ¡; ¡ ",.k - 10. Well Number At top of productive interval (Btm of 7" liner, 12380' MD/9784' TVD)¡ - 33-A.:.9Z1 ." !"" 1265' FSL & 1717' FWL of Sec.10, T9N, R13W, SM j Vf:FììF:[:D !. ..I.It: 5J""\.. A-15RD2 At total depth (13620' MD/9,783' TVD)! ~._~tL_- I.'" < 11. Field and Pool 73' FSL & 1338' FWL of Sec.10, T9N, R13W, SM "'..""" ",""._, """,.", 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Trading Bay Field 101' KB above MSL ADL-18731 Hemlock and "E" Pool 12. Date Spudded 13. Date TO. Reached 114. Date Comp., Susp. or Aband. 15, Water Depth, if offshore 16. No. of Completions 2/4/02 2/27/02 13620' MD 3/30/02 completed multi-lateral 73' 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120, Depth where SSSV set 121. Thickness of Permafrost 13620' MD/9783' TVD 13620' MD/9783' TVD Yes: X No: 340' feet MD NA 22. Type Electric or Other Logs Run LWD ADN (dipmeter) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Driven 13-5/8" 61# K-55 0 1073' 17-1/2" 1200 sx 0 9-518" 47# L-80 0 8157' 12-1/4" 1700 sx 0 7" 29# L-80 8010' 12380' 8-1/2" 1700 sx 0 4-1/2" 12.6# L-80 12197' 12700' 6" None 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 7926' 4-1/2" blankfslotted liner from 12380' MD to 12700' MD open to flow 3-1/2" 12246' 12226' (9784' TVD to 9797' TV D) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6" open hole lateral from 12700' to 13620' open to flow (9797' TVD to 9783' TV D) 27, PRODUCTION TEST Date First Production I, Method of Operation (Flowing, gas lift, etc.) 3/31/2002 Gas Lift (See A-15RD2L2 for initial test data) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/8/2002 24 TEST PERIOD => 0 0 0 NA 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. NA NA 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECFI\/FD "t. .-' "'=, . -"" j\p F(:2 5 '?!ì"¡? ",.LL.... AlasJ<a Oil & Gas Cans. ComrniSSWf¡ Anchorage OP!r:~I[\ll\L AFE #151723 . ! Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE R B OMS B F l MAY 19~ 2 ~~~~it in duplicate ,,-......, ,~ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 12351 9779 None Hemlock Rii"~,r'f-I\'ED' .\.tct~ V ' I """'r-.r',f">.""') ¡h. :.h... . / ,'\ /( Ii! ,,¡ ," L, '~f ,-, iJ'JL Alas]<a on & Gas Cons, Gon¡Wisslor AnchoragE! 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,5) ~ (1~, ~ Title Drillina Manaaer Date ú 1Vt: Q .25; ).òð L INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments, Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none", Form 10-407 Client.......... .........: UNOCAL Field. . .. . .. .. .. .. .. .. .. .: Trading Bay Unit Well.....................: A-15RD2 API number...............: 50-733-20105-02 Engineer.................: Carlos Pacheco COUNTY:..... .... .........: Monopod - Unocal 56 STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 0.00 ft KB above permanent.......: Top Drive DF above permanent.......: 101.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: ANADRILL SCHLUMBERGER Survey report 193.42 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 21-Mar-200205:03:10 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 12-06-01 20-Mar-02 140 1073.00 ft 13564.37 ft ) ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date............: 07-Feb-2001 Magnetic field strength..: 1107.61 HCNT Magnetic dec (+E/W-).....: 20.93 degrees Magnetic dip.............: 73.56 degrees _nn MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H.............. : Dip............ : of G...........: of H...........: of Dip.........: Criteria --------- 1002.03 mGal 1108.17 HCNT 73.57 degrees (+/-) 2.50 mGal ( + / - ) 6. 00 HCNT (+/-) 0.45 degrees ) ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 20.71 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 20.71 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 21-Mar-200205:03:10 Page 2 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 10425.10 36.40 162.40 0.00 8663.70 3380.47 -4076.40 2519.00 4791.91 148.29 0.00 TIP 2 10552.94 39.07 172.53 127.84 8764.89 3450.69 -4152.59 2535.73 4865.58 148.59 5.27 D-Mag 3 10648.27 43.08 172.50 95.33 8836.74 3509.19 -4214.68 2543.88 4922.89 148.89 4.21 D-Mag 4 10742.81 43.45 173.26 94.54 8905.59 3569.87 -4278.97 2551.91 4982.16 149.19 0.68 D-Mag 5 10835.97 44.77 174.82 93.16 8972.48 3631. 04 -4343.46 2558.64 5041.06 149.50 1. 83 D-Mag 6 10931.80 46.52 176.63 95.83 9039.47 3696.31 -4411.78 2563.73 5102.60 149.84 2.27 D-Mag - ) 7 11024.72 47.34 177.30 92.92 9102.92 3761. 41 -4479.57 2567.32 5163.10 150.18 1. 03 D-Mag - 8 11117.76 47.76 177.07 93.04 9165.72 3827.33 -4548.14 2570.69 5224.36 150.52 0.49 D-Mag 9 11189.83 47.93 177.35 72.07 9214.09 3878.63 -4601.50 2573.29 5272 .16 150.78 0.37 D-Mag 10 11281.24 47.92 178.10 91. 41 9275.35 3943.95 -4669.30 2575.98 5332.73 151.12 0.61 D-Mag 11 11375.27 48.92 177.79 94.03 9337.75 4011.73 -4739.59 2578.51 5395.59 151. 45 1. 09 D-Mag 12 11467.94 48.17 178.31 92.67 9399.10 4078.70 -4809.00 2580.87 5457.78 151.78 0.91 D-Mag 13 11561.70 48.79 180.68 93.76 9461.26 4146.83 -4879.19 2581.48 5520.01 152.12 2.00 D-Mag 14 11658.20 53.86 183.05 96.50 9521. 54 4220.62 -4954.45 2578.98 5585.49 152.50 5.59 D-Mag 15 11751. 73 58.48 186.05 93.53 9573.61 4297.36 -5031.86 2572.76 5651. 44 152.92 5.61 D-Mag 16 11855.65 63.26 189.89 103.92 9624.20 4387.68 -5121.70 2560.11 5725.91 153.44 5.62 D-Mag 17 11949.64 67.37 191.55 93.99 9663.44 4472.97 -5205.58 2544.21 5794.06 153.95 4.66 D-Mag 18 12045.12 70.35 193.11 95.48 9697.88 4561.99 -5292.57 2525.19 5864.12 154.49 3.47 D-Mag 19 12136.09 75.24 197.03 90.97 9724.79 4648.81 -5376.42 2502.57 5930.33 155.04 6.77 D-Mag 20 12232.70 75.39 194.74 96.61 9749.28 4742.17 -5466.30 2476.99 6001.33 155.62 2.30 D-Mag 21 12325.84 75.62 195.20 93.14 9772.59 4832.31 -5553.42 2453.70 6071.33 156.16 0.54 D-Mag - ) 22 12339.40 75.79 195.08 13.56 9775.94 4845.45 -5566.10 2450.27 6081.55 156.24 1. 52 D-Mag - 23 12430.25 79.07 194.57 90.85 9795.71 4934.08 -5651.81 2427.58 6151.11 156.76 3.65 D-Mag 24 12464.13 82.92 194.85 33.88 9801. 01 4967.53 -5684.17 2419.09 6177.52 156.95 11. 39 D-Mag 25 12497.28 87.35 194.46 33.15 9803.82 5000.54 -5716.12 2410.73 6203.68 157.13 13 .41 D-Mag 26 12521.04 91.06 194.22 23.76 9804.15 5024.29 -5739.13 2404.85 6222.62 157.27 15.65 D-Mag 27 12530.92 91.95 194.05 9.88 9803.89 5034.17 -5748.71 2402.44 6230.52 157.32 9.17 D-Mag 28 12566.90 91. 78 193.92 35.98 9802.72 5070.13 -5783.60 2393.75 6259.40 157.52 0.59 D-Mag 29 12638.56 92.26 193.94 71.66 9800.20 5141.74 -5853.11 2376.51 6317.18 157.90 0.67 D-Mag 30 12735.73 92.64 194.17 97.17 9796.04 5238.81 -5947.29 2352.93 6395.82 158.41 0.46 D-Mag ANADRILL SCHLUMBERGER Survey Report 21-Mar-2002 05:03:10 Page 3 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Beg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 12825.79 92.37 194.49 90.06 9792.11 5328.78 -6034.46 2330.66 6468.90 158.88 0.46 D-Mag 32 12920.07 93.77 193.59 94.28 9787.06 5422.91 -6125.79 2307.82 6546.10 159.36 1. 76 D-Mag 33 13000.21 93.05 194.71 80.14 9782.29 5502.90 -6203.36 2288.27 6611. 95 159.75 1. 66 D-Mag 34 13100.49 95.25 196.37 100.28 9775.03 5602.84 -6299.71 2261.47 6693.33 160.25 2.75 D-Mag 35 13193.79 91. 37 195.02 93.30 9769.65 5695.89 -6389.37 2236.28 6769.41 160.71 4.40 D-Mag 36 13287.27 92.02 195.62 93.48 9766.88 5789.28 -6479.48 2211. 60 6846.52 161.15 0.95 D-Mag - ) 37 13346.12 93.02 196.57 58.85 9764.29 5848.01 -6535.97 2195.30 6894.80 161. 43 2.34 D-Mag - 38 13380.28 90.99 199.00 34.16 9763.10 5882.04 -6568.47 2184.87 6922.32 161.60 9.27 D-Mag 39 13473.87 88.49 204.44 93.59 9763.52 5974.61 -6655.38 2150.25 6994.12 162.10 6.40 D-Mag 40 13564.37 80.29 211.11 90.50 9772.37 6061.75 -6734.97 2108.38 7057.27 162.62 11. 65 D-Mag 41 13620.00 80.29 211.11 55.63 9783.00 6113.68 -6781. 61 2080.05 7093.43 162.95 0.00 Proj. to bit [(c)2002 Anadrill IDEAL ID6_1C_I0J ) ~ ..-.... UNOCAL8 RKB to TBG Hanger = 40' Monopod Platform Well # A-15RD2L2 As run 3/23/02, rerun 3/28/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-112" 12.6 L-80 11.6Hyd511 blankliner12197' 13198' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 11.6 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 14235' 14939' 2-7/8" bull nosed hole finder joint on bottom of liner @ 15010' Tubing: 4-1/2" 12.6 N-80 3-1/2" 9.2 N-80 BTC BTC 40' 7926' 7926' 12246' t 12-1/4" hole to 8464' 9-5/8" at 8157' MD JEWELRY DETAIL NO. Depth Item 1. 340' Baker 4-1/2" TRDP-IA SSSV (ID = 3.813") 2. 7926' 4-1/2" x 3-112" crossover 2a 11408' Baker 3-1/2" CMD sliding sleeve (49 deg hole) 5. 12246' 3-1/2" tbg with 4.00" tubing seals 6 12197" Top of 4-1/2" liner with ZXP Liner top packer and with 4.000" seal bore from 12226' to 12241' Gas Lift Information 1 2085' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 3753' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 4892' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 5780' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 6451' 4-112" SFO-2 GLM with R-2 valve and RK latch 6 7027' 4-112" SFO-2 GLM with R-2 valve and RK latch 7 7604' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 8 8156' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 8750' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 9310' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 9866' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 12 10426' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 13 11046' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 14 11613' 3-1/2" SFO-2 GLM with R-2 orifice and RK latch 2a A-15RD2Ll, Junction = 13406' MD 7" liner cemented at 12380' MDI 9787' TVD, 76 deg hole """""""""",,"""""A-15RD2, 13620' MD TD A-15RD2, Junction = 12700' MD ................................. .............................. .............. A-15RD2L1 .................. ................. ........... 13730' MD TD ./=~_.-----.././::>// .-.-.-.-.-.-...LI A-15RD2L2 7 ~~ -= -1::~ MD Slotted Liner at Near-Horizontal in HB-l&2 9794' TVD 4-1/2" L-80, 11.6# tbg with 2-1/2" x 1/8" slots, 16 slots/ft 13198'-13330' and 14234'-14939', rest is blank liner A-15RD Redrill final 3-28-02 AOGCc.doc REVISED: 04/24/02 DRAWN BY: TAB ~ ,~ Sidetrack Drill A-15RD2 Unocal Alaska Drilling Daily Summary Report A-15RD2 2/3/02 to2/27/02 2/3/02 PU 8-1/2" sidetrack drilling BHA with PDC bit. RIH to shoe. 2/4/02 RIH with drilling assy, set down on cmt at 10189'. Drill to firm cmt at 10200'. Drill hard cmt to 10430', orient and sidetrack well at 1 0430', sliding 120 deg right from 1 0430' to 10469'. 2/5/02 Drill from 1 0469' to 10855'. 2/6/02 Drill from 10855' to 11055'. 2/7/02 Drill from 11 055' to 11206', POOH for bit. 2/8/02 Test BOPE. RIH with new bit, drill from 11206' to 11343'. 2/9/02 Drill from 11343' to 11678'. 2/10/02 Drill from 11678' to 11853'. POOH for bit. Bit was 1-1/4" undergauge. 2/11/02 RIH with new Hughes insert bit and ADN logging tool. Took wt at 11685', safety ream to bottom at 11853'. Drill from 11853' to 12013'. ..2/12/02 Drill from 12013' to 12275' 2/13/02 Drill from 12275' to 7" casing point at 12382'. Circ BU. POH logging MAD pass with ADN tool from 12280' to 11445'. 2/14/02 Pump hi-vis sweep, RIH to bottom at 12382', hole in good shape. Pump hi-density/hi- vis sweep, large quantity of small pieces of coal to surface. POH to shoe, drop pump out sub dart and mud dog. POOH, did not recover mud dog. Download ADN dipmeter info. Change rams to 7" and test. 2/15/02 Run 7" liner, 29# L-80 TKC buttress, 100 jts. Circ at shoe and run in open hole. Found mud dog in drill pipe, mud dog had been bent when dropped in drill pipe. 2/16/02 Finish RIH with 7" liner, no hole problems. Break Circ at 1.5 bpm and 650 psi, slowly increase rate to 4 bpm at 650 psi. Drop 1-3/4" kirksite ball, could not get ball to seat on landing collar. Drop 1-3/4" Phenolic 1.34 specific gravity ball. Ball landed on seat. Pressure up to 1600 psi to set hanger, pressure up to 2700 psi to release from hanger. Pressure up to 3400 psi to blow ball. Batch mix 31 bbl of 15.7 ppg cmt. Pump 20 bbl of chem wash, 20 bbl of 11 ppg Mud Push, 31 bbl of cmt. Drop DP wiper dart, displace with rig pumps 291 bbl of 9.4 ppg OBM. Bump plug to 2000 psi. PU and set ZXP liner top packer with 60K downweight. Pressure test packer to 1700 psi for 5 min, good. PU and reverse circ 2 DP volumes. POOH laying down 5" DP. A-15RD daily summary.doc 8 ,~ ....-..., 2/17102 Test BOPs. RIH with 6" drilling assy on 1.5 deg motor. PU 3-1/2" DP. Pressure test casing to 1700 psi for 10 min, no bleed off. Drill float track while dropping mud weight from 9.4 ppg to 9.1 ppg. 2/18/02 Drill below 7" shoe from 12382' to 12404', (slide to build angle from 12386' to 12404'). Perform FIT with 9.1 ppg mud to 650 psi with no leak-off (10.4 ppg EMW). Slide from 12404' to 12415', could not continue sliding. Rotary drill, OK. Pull bit due to inability to slide. POOH wet, dart for pump out sub hung up in 5" x 3-1/2" xover (wrong sub in BHA) Finish POOH. Motor stab was 6"+. MU new motor with 1.5 deg AKO with 5- 7/8" stab. RIH with new bit. 2/19/02 Slide drill from 12415' to 12468', pull bit due to lower than planned build rates and slow ROP from 12466' to 12468' in slide mode. RIH with new bit and 1.83 deg AKO motor. 2/20/02 Slide drill from 12468' to 12534', end of build to 92 deg. Rotary drill from 12534' to 12624'. Pull bit due to hrs and slowing ROP. 2/21/02 RIH with new insert bit and 1.15 deg AKO motor. Rotary drill from 12624' to 12795'. 2/22/02 Drill from 12795' to 13055'. POOH for new bit. 2/23/02 Test BOPE. RIH with new 6" bit, drill from 13055' to 13160'. Penetrated coal between HB-1 and HB-2 at 13090'. Had sharp build in rotary mode just below coal. 2/24/02 Slide from 13154' to 13194' at 180 deg down to knock down build from 95.25 deg to 91.1 deg. Rotary drill from 13194' to 13355'. POOH for bit. Saw some coal at 13100' and more coal from 13320' to end of bit run 13355'. 2/25/02 RIH with 5-314" x 2-1/2' long stabilized AND/Resistivity logging BHA. Could not push ADN stabilizer through 15 deg dog leg section at 12465', stuck pipe. Fire jars up and pull free. POOH and lay down logging BHA. RIH with drilling BHA with 1.5 deg AKO. 2/26/02 Drill from 13355' to 13515'. Slide on low side to drop angle and penetrate below coal. Some packoff problems from sloughing coal. 2/27102 Drill from 13515' to 13620' while dropping angle looking for good HB-2 sand. Formation change with better ROPs at 13541' MD/9768' TVD indicating good sand. Decided could not risk running logging tools through to sloughing coal at 13320'. Decided not enough horizontal zone from 13541' to 13620' TD in present well path. Will sidetrack on low side to penetrate good HB-2 sand earlier in the well. End of A-15RD2 A-15RD daily summary.doc 9 Well Name A-15 A-15RD A-15RD2 A-15RD2L 1 A-15RD2L2 ~ API # 50-133-20105 50-733-20105-01 Permit #201-189 50-733-20105-02 Permit #202-019 50-733-20105-60 Permit #202-048 50-733-20105-61 Permit #202-063 A-15RD well naming.doc ~ A-15RD Well Naming Explanation Depths. MD Status Cmt plug at 816' in prep for Kick-off 407 filed 12/14/01 Abdn Drill 12-1/4" hole from 1073' to 8464'. Set 9-5/8" csg to 8157'. Drill 8-1/2" hole to 12428'. Decided to geologic sidetrack. Set open hole cmt plugs up to 10430'. 407 report filed 2/14/02 for A-15RD abdnment Abdn Drill 8-1/2' sidetrack from 10430' to 12382'. Set 7" liner to 12380'. Drill 6" hole from 12382' to 13620'. Decide to geologic sidetrack. No plugs, low side sidetrack at 12700' Open to flow Not cased Therefore, in A-15RD2, 12700'-13620' is open to flow but not cased off with 4-1/2" slotted liner Open hole sidetrack 6" hole at 12700'. Drill 6" hole to 13730'. Bit trip on 3/8/02 unintentionally sidetracked well at 13406'. Could not reacquire old hole. Therefore, A-15RD2L 1 is from 12700' intentional sidetrack point to 13730'. Plugged w/debris 13406' -13730' Revised permit to deepen approved to 15,000' MD. Drilled 6" hole from unintentional sidetrack point at 13406' to 15042' TD. Ran slotted liner in 6" hole from 7" shoe at 12380' to 15010' TD. Slotted Liner Producing 1 /",-, UNOCALe RKB to TBG Hanger = 40' 2 t 12-1/4" hole to 8464' 9-5/8" at 8157' MD 2a .~ Monopod Platform Well # A-15RD2L2 As run 3/23/02, rerun 3/28/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8" 61 K-55 BTC 36.9' 1073' 9-5/8" 47 L-80 BTC 36.9' 8157' 7" 29 L-80 KC buttress 8010' 12380' 4-1/2" 12.6 L-8011.6Hyd511 blank liner 12197' 13198' 4-1/2" 11.6 L-80 Hyd 511 slotted liner 13198' 13329' 4-1/2" 12.6 L-80 11.6 Hyd 511 blank liner 13329' 14235' 4-1/2" 11.6 L-80 Hyd511 slotted liner 14235' 14939' 2-7/8" bull nosed hole finder joint on bottom ofliner @ 15010' Tubing: 4-1/2" 12.6 N-80 3-1/2" 9.2 N-80 BTC BTC 40' 7926' 7926' 12246' JEWELRY DETAIL NO. Depth Item 1. 340' Baker 4-1/2" TRDP-IA SSSV (10 = 3.813") 2. 7926' 4-1/2" x 3-1/2" crossover 2a 11408' Baker 3-1/2" CMD sliding sleeve (49 deg hole) 5. 12246' 3-1/2" tbg with 4.00" tubing seals 6 12197" Top of 4-1 /2" liner with ZXP Liner top packer and with 4.000" seal bore from 12226' to 12241' Gas Lift Information 1 2085' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 2 3753' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 3 4892' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 4 5780' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 5 6451' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 6 7027' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 7 7604' 4-1/2" SFO-2 GLM with R-2 valve and RK latch 8 8156' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 9 8750' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 10 9310' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 11 9866' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 12 10426' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 13 11046' 3-1/2" SFO-2 GLM with R-2 valve and RK latch 14 11613' 3-1/2" SFO-2 GLM with R-2 orifice and RK latch 7" liner cemented at 12380' MD/ 9787' TVD, 76 deg hole """"",""""Á-15RD2, 13620' MD TD ........................... ......,.....' A-15RD2Ll ................ ......1-3730' MD TD ...."" """"".':.............."""""" ......,.. ..' A-15RD2, Junction = 12700' M~................... ............... A-15RD2Ll, Junction = 13406' MD A-15RD Redrill final 3-28-02 AOGCc.doc .-.-.-.-.-.-.-£1 A-15RD2L2 7 ~~'~'I~~~ MD Slotted Liner at Near-Horizontal in HB-l&2 9794' TVD 4-1/2" L-80, 11.6# tbg with 2-1/2" x 1/8" slots, 16 slots/it 13198'-13330' and 14234'-14939', rest is blank liner REVISED: 04/24/02 DRAWN BY: TAB ,.,.-., , ~ A-15 Abandonment Daily Summary RECEIVED Unocal Alaska Drilling Daily Summary Report A-15 Abandonment 11/20/01 to 12/01/01 Ai. PP 'ì ; ?on? , ,\ ,.-. '.,¡ '- " <... AJasJ<a Oil & Gas Cons. ComrflisslOf' Anchorage 11/21/01 Move rig from A-9 to A-15. Pump down A-15's tbg with 43 bbl of FIW, 0 psi after pumping. 11/21/01 Pump 352 bbl of FIW down tbg x 9-5/8" annulus, pump 60 more bbl down tbg and both tbg and annulus on vacuum. RU APRS, RIH with 2.25" jet cutter, sat down at SSSV at 304'. POOH and left in hole the ceramic end of cutter. Remaining cutter full of parafin. Pumped down tbg, pressured up to 1100 psi. Shut down pumping, pressure suddenly dumped to 250 psi, resumed pumping. Shut down and tbg and annulus on vacuum. RU slickline and RIH with 1-1/2" tool string, slight drag at SSSV, RIH to to 2108', POOH. RIH with 2.20" gauge ring to 1810', started taking weight, POOH. RU APRS and cut tbg at 1370' with 2-1/8" jet cutter. RD APRS, ND tree. 11/22/01 NU BOPs, general rig modification in preparation to drill. Pump down 9-5/8" x 13-3/8" annulus with FIW at 1A bpm and 575 psi broke back to 450 psi at 1-1/4 bpm. Pumped 65 bbl. Pressure fell to 350 psi after shutdown. Pressure fell to 200 psi overnight. 11/23/01 Test BOPs. Finish rig work on brake bands, stairwell. 11/24/01 Pull and lay down 1363' of 2-7/8" tbg. RIH with 9-5/8" casing scraper to 1350', CBU and POOH. Pump 106 bbl of 10.4 ppg mud down 9-5/8" x 13-3/8" annulus at 4 bpm and 450 psi. Pressure declined to 300 psi as mud was pumped. Pressure fell from 300 psi to 250 psi at shutdown and to 195 psi in 2 hrs. Bled annulus to 0 psi, built back to 30 psi, bled annulus to 0 psi, built back,to 25 psi, bled annulus (1/2 gallon) to 0 psi, built back to 5 psi in 4-1/2 hrs. Bled annulus and stayed at 0 psi. 11/25/01 RIH with 9-5/8" retainer on drill pipe and set at 1280'. Pressure test 9-5/8" casing to 1000 psi. Mix and pump 35 bbl of 15.8 ppg cmt, displace below below retainer with 23 bbls FIW at 4 bpm and 1750 psi. Unsting and reverse two drill pipe volumes with just a trace of cement. Displace hole to 10.4 ppg mud. ND BOPs, ND tubing head. 11/26/01 Weld slips to 9-5/8" casing. NU BOPs and adapter spool to casing head. RIH with mechanical casing cutter. Cut 9-5/8" casing at 1173'. POOH with csg cutter. 11/27/01 PU spear and packoff, stab into top of 9-5/8" casing, circ two BU's, no problem. Release and LD spear. RIH and cut 9-5/8" at 78' RKB. POOH and LD cutter. RIH with spear and engage 9-5/8", recovered 36' of 9-5/8" casing. RIH with 13-3/8" cup tester to 45', test stack and connections to 1500 psi. RIH and spear casing at 78'. No movement up, circ cuttings out of hole, still no movement. Release spear. RIH and cut 9-5/8" casing at 1056', (17' above 13-3/8" shoe). POOH with cutter. RIH and spear 9-5/8" casing at 78'. Circ with very little cuttings to surface. POOH laying down 978' of 9-5/8" casing. A-15RD daily summary.doc .~ ..~ 11/28/01 Change rams to 5". Run 13-3/8" cup tester and test BOPs to 1500 psi. RIH with spear and jars. Engage casing fish at 1056'. Jar and circ at 8 bpm. Move fish up hole and recover all 117' of 9-5/8" casing. RIH with underreamer, clean out hole to 14" from 1074' to 1173'. Circ and POOH with underreamer. 11/29/01 RIH with 3-1/2" tbg ported cement stinger. Wash from 1173' to 1185', unable to wash deeper, POOH. Cut off ported stinger and RIH with 3-1/2" mule-shoed stinger. Wash from 1173' to 1214', unable to go deeper. 11/30/01 Pump 15 bbl FIW spacer, followeed by 80 bbls of 17.0 ppg cmt, displace with 1 bbl of FIW and 10.4 ppg mud. POH to 740', reverse circ with no cmt returns but some FIW in returns. Circ DP clean. Down squeeze 10 bbls up to 518 psi, leaked off to 490 psi in 15 min. Pump DP wiper dart. POOH with 3-1/2" cmt stinger. RIH with 12-1/4" bit and tag cmt at 785', polish cmt plug to 816' with 10k WOB. 12/1/01 Test cmt plug after 29 hrs to 786 psi, fell to 756 psi in 15 min. ND BOPs, NU new casing spool. A-15RD daily summary.doc 2 /""-.. .~ A-15RD Redrill Daily Summary Unocal Alaska Drilling Daily Summary Report A-15RD Redrill 12/2/01 to 2/2/02 12/2/01 Set 13-3/8" cup tester and test BOPs to 1500 psi. Rig repair and maintenance in preparation to drill. 12/3/01 Rig modifications for drilling ahead including electircal controls for mud pump troublehshooting, RU extra 300 bbl tank for mud storage and mixing, replace mud suction lines.to mud pumps. 12/4/01 Rig modifications for drilling ahead. 12/5/01 PU DP and stand back. Lost 10" dia mousehole cover down well. RIH with magnet on drill pipe, set down at 801', POOH with no recovery. RIH again with magnet, wash down to 811', POOH and recover fish. Test BOPE. 12/6/01 RIH with 12-1/4" drilling BHA. Drill hard cmt from 812' to 1083'. Cuttings started to sheen so rig down overboard chute and store cuttings in safeguard tanks. Continue drilling from 1083' to 1106'. 12/7/01 Drill from 1106' to 1183'. Perform FIT to 14.1 ppg EMW, (10.1 ppg mud with surface pressure applied of 240 psi at 1159' TVD/1183' MD.) Cuttings no longer sheening, drill ahead from 1183' to 1340', cuttings started to sheen again, mud logger showed good oil sand from 1275'-1340'. RD overboard cuttings chute and RU safeguard tanks. Drill from 1340' to 1463' while catching cuttings, MW at 10.3 ppg. 12/8/01 Drill from 1463' to 1653' while catching cuttings in Safeguard tanks, more oil sands at 1600', oil in mud increased from 1 % to 2%. Out of safeguard tanks. POH to shoe, waiting on more tanks. Drill from 1653' to 1850' (bottom of oil sand), out of safeguard tanks. POH to shoe. 12/9/01 Change out oil contaminated mud from pits. Send contaminated mud to Grayling via Isotanks. Clean up pits. 12/10/01 Change out oil contaminated mud from well to Isotanks and then to Grayling. Drill from 1850' to 2104' while catching cuttings in new safeguard tanks. Mud and cuttings passed sheen test, start overboarding cuttings. Drill from 2104' to 2176'. 12/11/01 Drill from 2176' to 2370'. Cuttings started failing sheen test at 2370', switch to catching cuttings. Drill from 2370 to 2470' while catching cuttings, passed sheen test, resume overboard dumping of cuttings. Drill from 2470' to 3124'. 12/12/01 Drill from 3124' to 3594'. POOH for bit change. 12/13/01 Test BOPE. RIH with PDC for Bit #2. Drill from 3594' to 4043'. A-15RD daily summary.doc 3 ~ .~ 12/14/01 Drill from 4043' to 4175'. Cuttings sheen test failed. Drill from 4175' to 4407' while catching cuttings. 12/15/01 Drill from 4407' to 4420', trip to change bits. PDC bit worn out after only 826', change to 12-1/4" insert bit. 12/16/01 Drill from 4420' to 4690', cuttings passed sheen test. Drill from 4690' to 5185' while dumping cuttings overboard. 12/17/01 Drill from 5185' to 5447', having trouble building angle. Circ BU for bit change. Cuttings failed sheen test on BU and started catching cuttings. POOH, change bits and motor. RIH with 12-1/4" insert bit. 12/18/01 Drill from 5447' to 5532'. Cuttings passed sheen test and resumed overboard with cuttings. Drill from 5532' to 6138'. Oil in mud content has decreased from 2% to 1.25%. 12/19/01 Drill from 6138' to 6739'. 12/20/01 Drill from 6739' to 7033', spot Soltex pill across coal from 6750' to 6980'. POOH for bit, pulled tight and backreamed from 6550' to 5270', bad coal at 6002'. 12/21/01 Continue to pump and back ream from 5270' to 2600' shoe. Packed off at 3690'. Pulled without pumping from 2600' to shoe at 1073' and on to surface. Test BOPE. MU MAD pass LWD assy. . 12/22/01 RIH with LWD tools to 5688' with some set downs from 4417' to 5553', minimal reaming required to work through set down spots. POOH logging while pumping and rotating from 5688' to 1089'. Spotted sheen on water while logging at 3600', mud and cuttings were passing sheen test but started catching cuttings. 12/23/01 Finished POOH. RIH with drilling assy, work through coal at 5620',5970', packed off and work pipe free. Wash and ream thru tight hole at 6420' and 6608', hole getting better below Soltex pill at 6700'. Resume overboard with cuttings at 6900'. Drill from 7033' to 7089'. 12/24/01 Drill from 7089' to 7474'. Wiper trip to 6532' with tight spot at 7170', normal amount of cuttings on circulation. Resume drilling from 7474' to 7487'. 12/25/01 Drill from 7487' to 7905'. 12/26/01 Drill from 7905' to 7911'. Long wiper trip to shoe at 1073', RIH to 7911' with several tight spots but only had to ream one spot from 6051' to 6065'. POOH for logs. 12/27/01 RU Schlumberger, RIH with FMS dipmeter on wireline. Set down at 5630', log from 5630' to shoe at 1073'. RIH with Dipole Sonic, Log from 5630' to surface. Test BOPE. A-15RD daily summary.doc 4 ,,-...,. ,~ 12/28/01 RIH with MDT on drill pipe. RU side entry sub at 3211'. RIH with E-line and make wet-connect. Obtain four good pressure points from 3215' to 3622' but then tool quit sealing. 12/29/01 Attempt to obtain fluid sample at 3241'. Unable to pump out sample. Lay down side entry sub and retrieve wireline. POOH and LD MDT tool. RIH with drilling assy. Set down at 4232',4680',4772',4960', work thru with minor difficulties. 12/30/01 Set down at coal at 5648', had trouble working through, packing off, worked pipe free, ream thru bad spot. Wash and ream down to 6820'. Packed off, PU to regain circ at 6340'. POOH to 5506', RIH to 6280'. Wash in hole from 6280' to 6815', packed off again. Pump out of hole to 6347', packing off again, work up to 6159' and regained full circ with lots of coal. 12/31/01 Mud pump suction screens plugging with coal. POOH to 5131', clean pits. RIH without problem to 5507'. Wash and ream down to 6950', hole packing off. Back ream out to 6628'. Ream in hole to 6853', packing off again. Work up and reestablish circ at 6800'. RIH and packing off again. Back ream to 6582' to establish circ. Wash and ream back in to 6853'. 1/1/02 Slide by bottom of coal from 6853' to 6861 " ream down to 7911' with tite spots. Drill from 7911' to 8218'. 1/2/02 Drill from 8218' to 8464'. Pump hi-vis sweep, pull for wiper trip to 5500' with some tite spots, pump out of hole to 6628', straight pull from 6628' to 5500'. RIH to 6860', unable to go deeper without drilling. 1/3/02 Orient to straight up and slide from 6853' to 6867', appears to be sidetracking and not acquiring old hole. Pump 35 bbl of 12.4 ppg hi-vis/hi-density sweep. Hole packed off as sweep rounded corner. POH to 5955' to regain circ. RIH from 5955' to 6840' with no problem. Spot 40 bbl Soltex pill, POOH with overpull at 6149', rest of trip good. 1/4/02 1/5/02 1/6/02 1/7/02 RIH with hole opener. Wash and ream from 5595' to 6279', RIH to 6841'. Wash to 6862', set down firm. Rotate with 40k to drill off to 6877' where reaming improved to 20K with good progress at 250 ft/hr. Work up and down from 6850' to 6890'. Wash and ream to 8464' TD with some tight spots. Circ BU and just a few large coal pieces. POH to 8150', pump 45 bbl of 11.5 ppg sweep, no increase in cuttings. Pull wiper trip to 5471', tite at 6840'. RIH, had to work thru 6185' and 6840' and ream 6895' - 6910', RIH to 8464' with 25' of fill on bottom. POH TO 8150', pump 11.5 ppg hi-vis sweep, no increae in cuttings on BU. POH to 6955', spot 43 bbl Soltex pill. POOH. Run 9-5/8" casing to 5500', had trouble circulating, work rate from 1 bpm to 7 bpm. Continue running casing, work through coal at 5635'. Casing stuck at 8157'. No circulation, eventually regain circulation. Pump 50 bbl of 11.0 ppg Mud Push spacer, 411 bbl of 12.0 ppg lead cmt, 41 bbl of 15.8 ppg tail cmt. Displaced with 10.4 ppg mud. Bumped plug to 2500 psi. Full A-15RD daily summary.doc 5 ~ ,~ returns throughout job, no cmt to surface. ND and PU BOP, install 9-5/8" casing slips, set slips with 275k. 1/8/02 Install 9-5/8" packoff, test to 3000 psi. NU BOPs. Start rig prep for drilling with OBM. 1/9-1/11 Prepare rig for OBM drilling. (Flood test deck, repair leaks, RU piping to OBM and base oil tanks) 1/12/02 Test BOPE to 3500/250 psi. RIH with 8-1/2" drilling BHA with PDC bit. 1/13/02 Test casing to 2730 psi, drill float track. Clean out 12-1/4" hole to 8460'. Displace well from 10.4 ppg WBM to 9.4 ppg OBM. 1/14/02 Drill 20' of new formation to 8484'. Perform FIT to 400 psi (10.4 ppg EMW) with no leak-off. Drill from 8484' to 8767'. 1/15/02 Drill from 8767' to 9138'. 1/16/02 Drill from 9138' to 9158', pull PDC bit due to low ROP. RI H with 8-1/2" insert bit, drill from 9158' to 9178', electrical problem on shakers, POH to shoe to repair same. 1/17/02 RIH and drill from 9178' to 9668'. 1/18/02 Drill from 9668' to 10210'. 1/19/02 Drill from 10210' to 10537'. POOH for bit. Test BapE. 1/20/02 RIH with new bit. Repair leak in glycol brake coolant line. Drill from 10537' to 10576'. 1/21/02 Drill from 10576' to 11050'. 1/22/02 Drill from 11050' to 11357', POH looking for washout, found same at 2600'. Change out jt and RIH. 1/23/02 Drill from 11357' to 11519'. Angle not building satisfactorily, pull bit. 1/24/02 RIH with new bit. Drill from 11519' to 11750'. 1/25/02 Drill from 11750' to 12075'. 1/26/02 Drill from 12075' to 12335'. 1/27/02 Drill from 12335' to 12428'. POOH while logging MAD pass with ADN dipmeter tool. Top of Hemlock deeper than expected. 1/28/02 Finish Mad pass up to 11 ,000'. POOH and download log data, send to Anchorage for analysis. Test BOPE. A-15RD daily summary.doc 6 ~ /~ 1/29/02 RIH with building assembly, motor with 1.83 deg AKO and 15 stands of drill pipe below HWDP. Set down at 8477'. Ream to 9060', difficult to enter old hole with building BHA. POOH. 1/30/02 Change motor setting from 1.83 to 1.50 deg AKO. RIH, set down at 9090'. Work down to 12270', packing off and losing returns. POOH, stuck at 11976'. Results of dipmeter (ADN) show that top of Hemlock is dipping donw to the east. Finalize directionlal plans to sidetrack to the west. A-15RD Abandonment 1/31/02 Work free and POOH. Run 2-7/8" tubing cement stinger for open hole abandonment and sidetrack plug. 2/1/02 RIH with stinger to 11800'. Mix and pump 11 bbls of 15.8 ppg cmt. 2/2/02 POH slow to 11180'. Spot 20 bbl hi-vis pill, POH to 10980'. Pump 8 bbl of 11.0 ppg Mud push spacer, 55 bbl of 16.4 ppg cmt, and 2 bbl of spacer. Displace plug with OBM. POH slow to 9700', drop drill pipe wiper dart and circ BU. POOH. A-15RD daily summary.doc 7 ~ ~. Sidetrack Drill A-15RD2 Unocal Alaska Drilling Daily Summary Report A-15RD2 2/3/02 t02/27/02 2/3/02 PU 8-1/2" sidetrack drilling BHA with PDC bit. RIH to shoe. 2/4/02 RIH with drilling assy, set down on cmt at 10189'. Drill to firm cmt at 10200'. Drill hard cmt to 10430', orient and sidetrack well at 10430', sliding 120 deg right from 10430' to 10469'. 2/5/02 Drill from 1 0469' to 1 0855'. 2/6/02 Drill from 1 0855' to 11 055'. 2/7/02 Drill from 11055' to 11206', POOH for bit. 2/8/02 Test BOPE. RIH with new bit, drill from 11206' to 11343'. 2/9/02 Drill from 11343' to 11678'. 2/10/02 Drill from 11678' to 11853'. POOH for bit. Bit was 1-1/4" undergauge. 2/11/02 RI H with new Hughes insert bit and ADN logging tool. T oak wt at 11685', safety ream to bottom at 11853'. Drill from 11853' to 12013'. . 2/12/02 Drill from 12013' to 12275' 2/13/02 Drill from 12275't07" casing point at 12382'. Circ BU. POH logging MAD pass with ADN tool from 12280' to 11445'. 2/14/02 Pump hi-vis sweep, RIH to bottom at 12382', hole in good shape. Pump hi-density/hi- vis sweep, large quantity of small pieces of coal to surface. POH to shoe, drop pump out sub dart and mud dog. POOH, did not recover mud dog. Download ADN dipmeter info. Change rams to 7" and test. 2/15/02 Run 7" liner, 29# L-80 TKC buttress, 100 jts. Circ at shoe and run in open hole. Found mud dog in drill pipe, mud dog had been bent when dropped in drill pipe. 2/16/02 Finish RIH with 7" liner, no hole problems. Break Circ at 1.5 bpm and 650 psi, slowly increase rate to 4 bpm at 650 psi. Drop 1-3/4" kirksite ball, could not get ball to seat on landing collar. Drop 1-3/4" Phenolic 1.34 specific gravity ball. Ball landed on seat. Pressure up to 1600 psi to set hanger, pressure up to 2700 psi to release from hanger. Pressure up to 3400 psi to blow ball. Batch mix 31 bbl of 15.7 ppg cmt. Pump 20 bbl of chem wash, 20 bbl of 11 ppg Mud Push, 31 bbl of cmt. Drop DP wiper dart, displace with rig pumps 291 bbl of 9.4 ppg OBM. Bump plug to 2000 psi. PU and set ZXP liner top packer with 60K downweight. Pressure test packer to 1700 psi for 5 min, good. PU and reverse circ 2 DP volumes. POOH laying down 5" DP. A-15RD daily summary. doc 8 ~ .~ 2/17/02 Test BOPs. RIH with 6" drilling assyon 1.5 deg motor. PU 3-1/2" DP. Pressure test casing to 1700 psi for 10 min, no bleed off. Drill float track while dropping mud weight from 9.4 ppg to 9.1 ppg. 2/18/02 Drill below 7" shoe from 12382' to 12404', (slide to build angle from 12386' to 12404'). Perform FIT with 9.1 ppg mud to 650 psi with no leak-off (10.4 ppg EMW). Slide from 12404' to 12415', could not continue sliding. Rotary drill, OK. Pull bit due to inability to slide. POOH wet, dart for pump out sub hung up in 5" x 3-1/2" xover (wrong sub in BHA) Finish POOH. Motor stab was 6"+. MU new motor with 1.5 deg AKO with 5- 7/8" stab. RIH with new bit. 2/19/02 Slide drill from 12415' to 12468', pull bit due to lower than planned build rates and slow ROP from 12466' to 12468' in slide mode. RIH with new bit and 1.83 deg AKO motor. 2/20/02 Slide drill from 12468' to 12534', end of build to 92 deg. Rotary drill from 12534' to 12624'. Pull bit due to hrs and slowing ROP. 2/21/02 RIH with new insert bit and 1.15 deg AKO motor. Rotary drill from 12624' to 12795'. 2/22/02 Drill from 12795' to 13055'. POOH for new bit. 2/23/02 Test BOPE. RIH with new 6" bit, drill from 13055' to 13160'. Penetrated coal between HB-1 and HB-2 at 13090'. Had sharp build in rotary mode just below coal. 2/24/02 Slide from 13154' to 13194' at 180 deg down to knock down build from 95.25 deg to 91.1 deg. Rotary drill from 13194' to 13355'. POOH for bit. Saw some coal at 13100' and more coal from 13320' to end of bit run 13355'. 2/25/02 RIH with 5-3/4" x 2-1/2' long stabilized AND/Resistivity logging BHA. Could not push ADN stabilizer through 15 deg dog leg section at 12465', stuck pipe. Fire jars up and pull free. POOH and lay down logging BHA. RIH with drilling BHA with 1.5 deg AKO. 2/26/02 Drill from 13355' to 13515'. Slide on low side to drop angle and penetrate below coal. Some packoff problems from sloughing coal. 2/27/02 Drill from 13515' to 13620' while dropping angle looking for good HB-2 sand. Formation change with better ROPs at 13541' MD/9768' TVD indicating good sand. Decided could not risk running logging tools through to sloughing coal at 13320'. Decided not enough horizontal zone from 13541' to 13620' TD in present well path. Will sidetrack on low side to penetrate good HB-2 sand earlier in the well. End of A-15RD2 A-15RD daily summary.doc 9 .~ ~ Start of Sidetrack A-15RD2 L 1 Unocal Alaska Drilling Daily Summary Report A-15RD2L 1 2/28/02 to 3/8/02 2/28/02 3/1/02 3/2/02 3/3/02 3/4/02 3/5/02 3/6/02 3/7/02 3/8/02 POOH with tite spots in 7" liner at 8675' and 8120' (cuttings beds). Finish POOH. RIH with sidetrack drilling assy and LWD slick ADN logging tools. Set down and work thru cuttings beds at 11971'. Wash and ream from 11971' to 12247', tag at 7" shoe at 12382' and ream thru. Orient 1 .5 AKO motor to high side and run in open hole with no problems to logging depth of 13280'. MAD pass from 13280' to 12700' with no hole problems, 300'/hr, 60 rpm, 240 gpm. Open hole sidetrack on low side of hole at 12700'. Time drill slide straight down from 12700' to 12740'. Slide drill sidetrack hole from 12740' to 12779'. Rotate and slide from 12779' to 13063'. Pull bit due to high torque and hrs. MAD pass from 13063' to 7" shoe at 12380' . Circ BU in 7" liner at 12368', hole packed off. Drop dart to open pump-out sub, pump 11.7 ppg hi-density sweep with cuttings returns. Observed 10k loss on up stroke after sweep to surface. POOH with no further hole problems. Download LWD logs, test BOPE. RIH with 6" bit. Orient at 180 deg down at 12611' and trip in new hole with no problems. Drill from 13063' to 13281'. Drill from 13281' to 13369'. Pull bit. RIH with new bit. Trip through sidetrack point without orienting, saw two small 5k bobbles at 12700'. Check shot survey at12780' indicated entered old hole. POH to 12685' and orient down at 165 deg R. RIH in new hole with no problems. Drill from 13369' to 13507'. Drill from 13507' to 13730'. Trip for new bit. Circ, rotate and reciprocate at sidetrack point from 12715' to 12760' bit depth. RIH with new bit without orienting at sidetrack point. Check shot at 12775' indicated in old hole. PU and orient 5 times to work through sidetrack junction, ream from 12687' to 12762', fell through to 12783' and surveyed in new hole. RIH, set down at 13123' and 13230' and fell thru. Ream with no resistance from 13346' to 13406'. Hard resistance at 13406', ream 13406' to 13420'. Obtain approval from AOGCC on 3/8/02 to drill deeper to 15,000' MD, Approval #202- 063. This was coincidental to the unintentional sidetrack on 3/8-9/02. End of A-15RD2L 1 A-15RD daily summary.doc 10 . ~ I~ Start A-15RD2L2 3/9/02 Continue reaming with hard resistance to 13494'. Check shot indicates sidetracked well at appx 13406'. Drill from 13494' to 13627'. 3/10/02 Drill from 13627' to 13660'. POH to 12693', RIH without pumping or rotating and tag bottom of new hole at 13660'. POOH for new bit. Test BOPE. RIH with 2-7/8" tubing hole finder/liner simulation assembly on drill pipe and MWD. 3/11/02 RIH with 2-7/8" tbg joint/bullnose. Tag at 13660' and MWD confirms that BHA is in new hole. POOH with simulated liner BHA. RIH with drilling BHA. Orient low side before tripping through sidetrack point at 12700', still on low side tool face when trip through 2nä sidetrack point at 13406', no problems in new hole to 13660' TD. Drill from 13660' to 13683'. 3/12/02 Drill from 13683' to 13992'. 3/13/02 Drill from 13992' to 14021'. Trip for bit. RIH with new bit, orient to low side at 12600' and RIH with no problems to 14021'. Drill from 14021' to 14026'. 3/14/02 Drill from 14026' to 14256'. 3/15/02 Drill from 14256' to 14269'. Trip for new bit. No hole problems. Drill from 14269' to 14340' . 3/16/02 Drill from 14340' to 14526'. 3/17/02 Drill from 14526' to 14558'. Trip for new bit. Two 30k bobbles while POOH at 13305' and 13201'. No problems on trip in hole. Drill from 14558' to 14564'. 3/18/02 Drill from 14564' to 14838'. Trip for bit. 3/19/02 30k to 40K overpulls at 13368' to 13350', more overpull at 13200'-13198', and 12882'. RIH with new bit to shoe, change out drilling line. RIH with 30K bobble at 12840' and 13244'. Drill from 14838' to 14891'. 3/20/02 Drill from 14891' to 15042' TD. POOH to run liner. 3/21/02 Run 4-1/2" slotted liner with 2-3/8" inner string to 15010', no problem. 3/22/02 Set liner hanger, pump base oil displacement through inner string. Set liner top packer, test casing to 1500 psi. POOH LDDP. 3/23/02 Cont'd LDDP, R/U to run completion. 3/24/02 RIH with 31/2" x 41/2" Completion. Tagged Seal Bore Locator at 12,251.10. Land Tubing Hanger, N/D BOP equipment. A-15RD daily summary.doc 11 /'. ~ 3/25/02 N/U and test Tree for 5,000 psi. RlU SIL, RIH shifting tool - sat down at 5,820' in attempt to open CMD sleeve at 11,408'. POH changed roller bar spacing, re-RIH, would not go deeper than 3,730'. POH RD Silo 3/26/02 N/D Tree, N/U BOP and test to 3,500 psi. 3/27/02 Pulled tbg hanger & seal assy wi 42 klbs. RlU SIL, circ condo Mud. RIH wi shifting tool, attempted to open CMD sleeve at 11 ,412' WLM - would not open. POH shifting tool. Pumped 150 bbls thinner mud down tubing. RIH w/shifting tool to open CMD sleeve, wire parted at sheave when pulling 1200 Ibs @ the unit - caught parted wire wi packoff. POH & RID Silo 3/28/02 POH wi completion string - checked CMD sleeve function properly, changed out seal units, re RIH completion string with CMD sleeve in open position. Landed tubing hanger, set BPV. 3/29/02 NO BOP, NU tree. Displace well to diesel through open sliding sleeve. 3/30102 RIH with wireline, shift sliding sleeve closed. Run slickline BHP survey at 11400' MD. POH and RO wireline. Release well to production at 08:00 on 3/30102. End of A-15RD2L2 A-15RD daily summary.doc 12 ,~ ~ A-15RD Well Naming Explanation Well Name API # Depths, MD Status A-15 50-133-20105 Gmt plug at 816' in prep for Kick-off 407 filed 12/14/01 Abdn A-15RD 50-733-20105-01 8-112" hole, 10430' -12428' Abdn Plugged in prep for geologic sidetrack #1 407 filed 2/14/02 50-733-20105-02 6" hole from 12700' to 13620' Open Hole to flow Hole too high in TVD and coal unstable But will not be cased Decided to open hole sidetrack 50-733-20105-60 Open hole sidetrack 6" hole at 12700' Open Hole Surface to permit depth of 13687' MD Will have slotted liner A-15RDST1 A-15RDST1 L 1 A-15RDST1L 1DP 50-733-20105-61 Revised permit approved to 15,000' MD Open Hole Same as above well except "deepen" Will Have Slotted liner Surface to eventual TD. A-15RDST1 L 1 PB 1 50-733-20105-70 Unintentional 6" sidetrack hole 12406' to 13730' Plugged with debris RECEIVED MAR 1 3 2002 Alaska Oil & Gas Coos. Commission Anchol'age A-15RD well naming.doc (' , ./-\ Unocal Alaska Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519.6247 Telephone (907) 276-7600 UNOCAL8 RECE'~ co".. ~ . . COMM COMM t---1 SR RES ENG . i RES ENG --r-¡ SR ENG 0 FE SR GEOL B 0 4 200' GEOL AI~..rul&"'-"'" .GEOL ASST UilftllUi ~Coos. '. T TECH Anchorage . STAT TECH February 1,2002 Ms. Cammy Taylor Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 VIA U.S. MAIL VIA FACSIMILE: (907) 276-7542 Re: Trading Bay Unit/Trading Bay Field Alignment Agreement Dear Chair Taylor: On December 27,2001, Union Oil Company of California (Unocal) and Forest Oil Corporation (Forest) entered into an Alignment Agreement for the Trading Bay Unit (TBU) and Trading Bay Field, ADL 18731 (TBF) with an effective date of January 1, 2002. By letter to the Department of Natural Resources (DNR) dated December 29, 2001, Unocal apprised the DNR of this agreement and copied the Alaska Oil and Gas Conservation Commission on the same. To reiterate, Unocal and Forest now share a common equity ownership of 53.20% and 46.80% respectively, in the oil-bearing horizons for both the TBU and TBF. Thus, irrespective of individual lease ownerships, the relative aligned interests inside the TBU and TBF are the same. Please let me know if you have questions regarding this transmittal. I may be reached at (907) 263-7882. Very Truly Yours, ;?9r~ Shannon W. Martin Project Landman ILE -, ~ ~V~VŒ (ID~ ~~~~[{~ ALAS IiA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson Drilling Manager Unocal PO Box 196247 Anchorage AK 99501 ,l{¡: /.ÎY-1l1M ¡J~ 1'>. Re: ~gJ3ayFieldA-15 RDSTI Unocal Permit No: 202-019 Sur Loc: 1616' FSL, 576' FEL, S4, T9N, R13W, SM Btmhole Loc. 1193' FWL, 63' FSL, SlO, T9N, R13W, SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Trading Bay Field A-IS RDSTl. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (J~ Dúl~ !yv.,W CammyOC!>echsli TayloØ Chair BY ORDER OF THE COMMISSION . DATED this 1st day of February, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. '- !--- .U4,{¡- l-{ I ( 0 1- )( ;) ( l ..oJ J1U Ii ;) /ì /ð~- ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work Drill 0 RedriIl0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (Unocal) 101 KB, MSL feet Trading Bay Field - Monopod Pltlm. 3. Address 6. Property Designation Northern Nose Hemlock P.O. Box 196247, Anchorage, AK 99519 - 6247 ADL 18731 ~g ~¡fn ofl~t surface 7. Unit or property name 11.TypeBond (SEE 20 ACC 25.025 h ,~,?L, .~~)-, 54, T9N, R13W, SM Trading Bay Field AK Statewide Oil & Gas Bond ~ /.~ of PJid &five interval 8. Well number Number 1735' FWL, 1382' FSL, S10, T9N, R13W, SM A-15 RDST1 U62 - 9269 At total depth 9. Approximate sWtJate Amount 1193' FWL, 63' FSL, S10, T9N, R13W, SM ~ ló~ $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 63 feet @ TD '(K-13 Rd2) 1128 feet 3840 13,716/9,725 feet 16. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 (e)(2» Kickoff depth 10700 feet Maximum hole angle 92.29 Maximum surface 3073 psig. At total depth ("13,716' 4,043 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 13-3f8" 61# K-55 BTC 1,034' 39' 39' 1,073' 1,073' Existing csg (1200 sx) 12-1/4" 9-5/8" 47# L-80 BTC 8,160' 0' 0' 8,160' 6,780' Existing csg (1700 sx) 8-1/2" 7" 29# L-80 BTC 4,273' 8,060' 6,680' 12,333' 9,793' 750 sx 6" 4-1/2" 11.6# J-55 Hyd511 2,059' 12,230' 9,700' 13,716' 9,725' None 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 12.428 feet true vertical 9,830 feet Effective depth: measured 12.428 feet PBTD true vertical 9,830 feet Packer @ 6167' MDt 5524' TVD Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,028' 13-3/8" 1,200 sx 1,073' 1,073' Intermediate 8,160' 9-5/8" 1,700 sx 8,160' 6,780' 20. Attachments Filing fee 0 Property plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I here:çgfy that thYr~~Vlrue and correct to the best of my knowledge ! A Iii/a J I I ^ '" Date;). I-I ) Signed ß,q \ Title Drilling Manager Commission Use Only Permit Number 6/1 API numb~r - . & ì z.-I Approval date See cover letter :;z.ð 2- - 50- 733- 2D/O '~O for other requirements Conditions of approval Samples required 0 Yes.~ No Mud log required 0 Yes [(' No Hydrogen sulfide measures ':8( Yes 0 No Directional survey required .~ Yes 0 No Required worki~g pressure for BOPE 0 2M; 0 3M; 0 5M; 0 10M; 0 15M Other: Tes'\- ß,d P f -{v"S5 00 fevl ~G,{. by the order of Approved by Commissioner the commission Date IJ .. Form 10-401 Rev. 12-1-85 L RECEI~D Fei:,. cJ, ZOO? ORiGll\~AL Alaska 011 & Gas Cons. Commission Anchorage "........... /"""""\. Monopod A-15RDST Hazard Analysis for APD 20AAC 25.005 (c) 4 (A) The Hemlock production in the area has an H2S con~nt of up to 400 ppm. Prior to drilling the A- 15RD, a full cascade system and individual SCBA's will be in place. An H2S Safety Technician will service the equipment, conduct drills and refresh crew members in the proper use of the equipment. (B) Other than H2S, there is no real hazard issue regarding this well other than well bore mechanics APD procedure and Hazard A-15RD.doc 1/31/2002 <" .~ ..-... Monopod Well #A-15RDST1 Maximum Anticipated Surface Pressure The following present data used for calculation of anticipated surface pressures (ASP) during drilling of the A-15RDST1. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling íinJ (TVD ft) (Ibs/gal) (lbs/gal) (lb/qal) {Q§j} {Q§j} 13-3/8" 1073 13.2 8.9 9.2 450 629 9-5/8" 6780 14.4 8.1 9.2 2855 3106./ 7" liner 9793' 14.6 8.1 9.4 4082 3074 4-1/2" 9725' 8.1 9.4 4054 slotted liner Procedure for Calculatinq Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with full evacuation) or 2) formation pore pressure at the next casing point less gas gradient to the surface as follows: For 12-1/4" Hole Section from 1073' TVD to 6780' TVD = (FGx.052xDshoe) - (.1xDshoe) = (13.2 x .052 x 1073) - (.1 x 1073)= 629 psi OR = FPP - (0.1 gas gradient xD) = 3153- (.1 x (7900) = 2363 psi For 8-1/2" Hole Section from 7900' TVD to 9610' TVD 1) ASP 2) ASP 1) ASP 2) ASP = (FGx.052xDshoe) - (.1xDshoe) = (14.4 x .052 x 6780) - (.1 x 6780)= 4399 psi OR = FPP - (0.1 gas gradient xD) = 4082 - (.1x 9763) = 4082 - 976 ./ = 3106 psi For 6" Hole Section from 9793' TVD to 9725' TVD @ TD 1) ASP 2) ASP = (FGx.052xD) - (.1xD) = (14.6 x .052 x 9793) - (.1 x 9793)= 6454 psi OR = FPP - (0.1 gas gradient xDShoe) = 4054 - (.1x 9793) = 4054 - 980 = 3074 psi ,--- ~ '. ./ 1 RIH with 8-1/2" PDC side track bit, wash any contaminated cement at 10,200'MD, and sidetrack as per well attached well plan to landing point at 12,333' MD 197/93' 2 Circulate hole clean and POOH. ~ ,/ 3 Run and cement 7" 29 ppf L-80 liner. See attached cementing program. Procedure Summary of Proposed A-15RD Redrill (See Separate Description Summary for A-15ST1 Proposed abandonment) 20 AAC 25.005(c) 5, 13 and 14 4 M/U.6" PDC bit on steera~ assembly. Drill out shoe track, and continy~ drill 6" ho~izontal hol! section to TD at 13,716' MD / 9,725' TVD. Circulate and POOH. F/òN/ÞE/U!(\-'¿i.;7 1/ {;Cè, -{.., -¡:'D, .,/ 1< ¿co ~ -.::.::t '/ .~ 5 Run 4-1/2" slotted liner with inner string. Displace oil base mud below 7" packer with base oil, and set 5" Liner hanger and packer. POOH with running tool. v 6 Set 7" permanent packer at appx 12,230'. ./' 7 Run 4-1/2" x 3-1/2" tubing with gas lift mandrels. 8 Space out and stab seals in packer while landing hanger. 9 ND BOPE, NU tree. 10 R/U Wireline & Pumping tee, RIH and open 3-1/2" Baker CMU sliding sleeve. Displace the well with diesel. Close CMU sliding sleeve, POH & RID wireline. 11 Move rig and place well on gas lift production. The cuttings will be collected in safeguard tanks and will be injected to Bruce G-3 waste disposal well when permit is received. APD procedure and Hazard A-15RD.doc 1/31/2002 .---- ~ '- Monopod A-15RDST1 Cementing Program 7" 29 ppf, L-80 BTC Liner usinq 15.8 ppq G neat system 8-1/2" hole @ 12,333' MD, Liner Lap @ 8,060' MD Cement volume for liner based on open hole volume plus 20%, and shoe track. Estimated volume is: 4193' x 0.02258 bbls/ft x 1.20 = 114 bbls = 638 cuft 80' shoe jts x 0.03645 bbl/ft = 3 bbls = 16 cuft v Total Cement = 638 + 16 = 654 cuft of 15.8 ppg or 750 sxs of G-Neat cement. 4-1/2" Liner ",/ Slotted liner will not require any cement UNOCAL(Ð A-15RDST1 Schlumberger ( Report Date: January 31,2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: Unocal Vertical Section Azimuth: 193.420° Field: Trading Bay Unit 01/~ ~1/02 Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Monopod / A-15 APproved TVD Reference Datum: KB Well: A-15 TVD Reference Elevation: 101.0 ft relative to Mean Sea Level Borehole: A-15RDST1 UWI/API#: 507332010501 Magnetic Declination: 20.917° Survey Name I Date: A-15RDST1 (P18) / January 31,2002 Total Field Strength: 55396.236 nT Tort I AHD I DDII ERD ratio: 231.968° /8219.58 ft /6.426/ 0.83E Magnetic Dip: 73.564° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: February 07,2001 Location LatiLong: N 60.89685919, W 151.57882073 Magnetic Declination Model: BGGM 2001 Location Grid N/E YIX: N 2523130.000 flUS, E 218859.000 flUS North Reference: True North Grid Convergence Angle: -1.37957061° Total Corr Mag North.> True North: +20.91 yo Grid Scale Factor: 0.99998994 Local Coordinates Referenced To: Well Head Proposed Well Profile - Geodetic Report Station ID I MD I Incl I Azim I TVD I VSec I N/.S ft Tie In Survey 10613.41 38.23 158.89 8813.54 3477.05 -4184.42 N 60.88541253 W 151.56447696 KOP Cry 6/100 10700.00 37.88 158.13 8881.73 3520.82 -4234.09 N 60.88527665 W 151.56436729 Cry 4/100 10800.00 41.33 165.85 8958.81 3575.20 -4294.65 N 60.88511099 W 151.56425780 -4360.71 N 60.88493028 W 151.56418138 -4430.64 N 60.88473899 W 151.56413343 End Cry 11088.07 48.34 178.86 9163.40 3764.31 -4495.14 2620.11 4.00 2518573.14 221370.10 N 60.88456256 W 151.56411499 ( Cry 6/100 11549.36 48.34 178.86 9470.01 4097.89 -4839.73 2626.98 0.00 2518228.49 221368.67 N 60.88361997 W 151.56407687 11600.00 50.58 181.56 9502.92 4135.35 -4878.20 2626.82 6.00 2518190.03 221367.58 N 60.88351474 W 151.56407782 11700.00 55.16 186.43 9563.29 4213.95 -4957.66 2621.17 6.00 2518110.73 221360.02 N 60.88329740 W 151.56410963 11800.00 59.92 190.77 9616.96 4297.98 -5041.02 2608.48 6.00 2518027.70 221345.33 N 60.88306938 W 151.56418096 11900.00 64.80 194.71 9663.36 4386.51 -5127.36 2588.89 6.00 2517941.86 221323.66 N 60.88283322 W 151.56429101 12000.00 69.78 198.34 9701.97 4478.57 -5215.74 2562.63 6.00 2517854.14 221295.29 N 60.88259149 W 151.56443850 12100.00 74.83 201.74 9732.36 4573.15 -5305.18 2529.96 6.00 2517765.51 221260.47 N 60.88234686 W 151.56462197 End Cry 12103.37 75.00 201.85 9733.24 4576.37 -5308.20 2528.76 6.00 2517762.52 221259.20 N 60.88233860 W 151.56462871 Target 12303.37 75.00 201.85 9785.00 4767.46 -5487.51 2456.86 0.00 2517585.00 221183.00 N 60.88184816 W 151.56503245 7" Csg Pt 12333.50 75.00 201.85 9792.80 4796.26 -5514.53 2446.02 0.00 . 2517558.25 221171.52 N 60.88177426 W 151.56509331 Cry 13/100 12343.37 75.00 201.85 9795.35 4805.68 -5523.37 2442.48 0.00 ¡ 2517549.49 221167.77 N 60.88175008 W 151.56511319 12400.00 82.36 201.85 9806.46 4860.58 -5574.88 2421.82 13.00J 2517498.50 221145.87 N 60.88160919 W 151.56522920 A-15RD (P18) Report.xls Page 1 of 2 1/31/2002-2:42 PM -' 90° Point End Cry TO Station ID Le~al Description: ( ( Surface: 1616 FSL 576 FEL 84 T9N R13W SM Tie-In: 2711 F8L 3306 FEL 810 T9N R13W SM Target: 1408 F8L 3406 FEL 810 T9N R13W SM TO 1 BHL: 102 F8L 3932 FEL 810 T9N R13W SM NorthinQ (y) rftUSl 2523130.00 2518885.32 2517585.00 2516292.00 A-15RD (P18) Report.xls .J Page 2 of 2 EastinQ (X) rftUSl 218859.00 221313.04 221183.00 220628.00 N 60.88146051 W 151.56535161 N 60.88138360 W 151.56541489 N 60.87827605 W 151.56797290 1/31/2002-2:42 PM ~ ~ VERTICAL SECTION VIEW ~~ ~ UNO[AL~ Client: Unocal Well: A-15RDST1 Field: Trading Bay Unit Structure: Monopod Section At: 193.42 deg ......... Q) > Q) :;:;-~ Q) ro ~ Q) O(j) 0 c: 0 ro C\I Q) II ~ c: Q) .- > ...... 0 - ..c ~ ro 15..:= Q)O O~ - ...... roo 0...... :e- Q)CJ >~ Q)';"": ::J Q) .....0::: r- > Q) W Date: January 31, 2002 -2000 0 .------ 2000 4000 6000 8000 10000 12000 -2000 2000 4000 Vertical Section Departure at 193.42 deg from (0.0,0.0). (1 in = 2000 feet) 6000 0 Schlumberger TD 1371BMD 9725TVD 201.85" az B159 departure End Crv 12489 MD 9809 TVD 93.94' 201.85' az 4948 departure UNOCALG -4000 4000 2000 ^ ^ ^ I ~ a:: 0 z 0 -2000 I ~ => -4000 0 en v v v -6000 -8000 -4000 /'- ~. PLAN VIEW Client: Unocal Well: Field: Structure: A-15RDSTl Trading Bay Unit Monopod 1 in = 2000 ft 31-Jan-2002 Schlumberger Scale: Date: -2000 0 2000 4000 True North Mag Dee ( E 20.920 ) TIe In Survey 10613 MD 8814 TVD 38.23' 158.89' az 4184 S 2556 E TO 13716MD 9725TVD 93.94' 201.85' az 6794 S 1933 E EndCrv 12489 MD 9809 TVD 93.94' 201.85' az 5657 S 2389 E -2000 «< WEST 2000 EAST »> 4000 0 4000 2000 0 -2000 -4000 -6000 -8000 RE:A.15RdSt-1 r--- ~ Subject: RE:A.15RdSt.1 Date: Fri, 1 Feb 2002 15:25:32 -0800 From: "Rachmadi, Bambang - Alaska" <brachmadi@unocal.com> To: "'tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak.us> I am sorry Tom, but can you pis forward this to Steve? This is the 4th time I tried to send him. Thankyou. Bambang > --Original Message---- > From: Rachmadi, Bambang - Alaska > Sent: Friday, February 01, 20022:21 PM > To: 'tom_maunder@admin.state.ak.us'; 'steve_davis@admin.state.ak.us' > Subject: > Importance: High > > Steve, > > I forgot to include the logging program for the sidetrack. It's going to > be > memory AON-dipmenter LWO from 11,000' to 12,333'. > > I would like also to clarify that the surface location of this A-15RdSt1 > is > @1616' FSL & 576' FEL of 5ec.4, T9N, R13W, SM. > > I also just dropped the copies and check 15 mins ago at your front desk > there. > > Appologize for the inconvinience > > Thanks & regards > Bambang Rachmadi > > > 1of1 211/022:49 PM ~, ,~ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager January 31, 2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Cammy Taylor Application fro Permit to Drill (Form 10-401) Trading Bay Field Monopod Platform, Well A-15RDST1 Dear Commissioner Taylor: Enclosed is an Application for Permit to sidetrack Well A-15Rd (Form 10-401) at Monopod Patform. A separate Sundry Application (Form 10-403) was also sent to you for the proposed P&A of A-15Rd well at the top of Hemlock. The Hemlock formation found to be deeper than expected. With current wellbore georTJetry, it will be difficult to continue drilling without penetrating oil water contact and will be 10,Ø'sing at least 125' lateral drill lateral out of the 650' expected. . The well will be sidetracked to soutwest of current well bore, for approximately 1300' lateral and 10-20' gain in structure that obviously will improve production rate and life of the well. The expected spud date for this A-15RDST1 is February 1 st, 2002 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659 or Bambang Rachmadi at 263-7808. ~ Dan Williamson Drilling Manager RECEIVED JAN 3 1 2002 Alaska 011 & Gas Cons. Commission Anchorage AOGCC cover letter A-15RD2 APD_2.doc ~, ,~ FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITIED DATE CHECK NO, 1031548 01-Feb-0 2004730 NET 01-FEB-02 DRILLPERMITA15R 02023000001 100.00 100.00 }(} ,~! ~ ]? J)sr-' ,\ laska Oil & Gas Coos, Go A \1 chofage FORM 4-2B181 (REV 11-95) PRINTED IN U,SA DETACH STUB BEFORE DEPOSITING CHECK 100.00 100.00 CITIBANK DELAWARE A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 62-20 311 Union Oil CQmpany of California Accounts Payable Field Dìsbursing 2004730 UN.OCAL€Ð Pay One Hundred Dollars And 00 Cents***********~*'**~*************** To the order of 01-FEB-02 Check Amount ******100.00 Date STATE OF ALASKA ALASKA OIL & GAS CONSERVAT!ON COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States II' 200lt? ~Oll' 1:0 ~. .00 2091: Void after six months from above date. -- -? ----~ ---- ~ 9 . . 8 . ~ ? II' ~ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITER/PARAGRAPHS TO BE INCLUDED IN TRANSNDTTAL LETTER WELLNAME"/D .sf /1~/,$;:KÞ..sï~ I CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new well bore segment of existing weD -----' Permit No, API No. . (If api number last two (2) Production should continue to be reported as a function .of digits are between 60-69) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(1), all records, data and REDRILL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from / records, data and logs acquired for well (name on permit). EXPLORA nON ANNULAR DlI~SAL Annular disposal has not been requested. .. ( ). 0 \7 INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . <--) YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRILL THIS WELL DJSPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <--) YES + SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY W'1oCA.-I WELL NAME -r15 ~r A-If> Æ?J:>.5"" / PROGRAM: Exp Dev ,,/' R~L/ Serv Wellbore seg Ann. disposal para req FIELD & POOL Pj;r)[~~ INIT CLASS J;;;¡E, V 1 OIL GEOL AREA B 2.6 UNIT# ,IV; ,4, ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. JI"i... . . . . . . . . . . . . . . . . . . . . ';' 2. Lease number appropriate. """"""""" 'N 3.Uniquewellnameandnumber.................. Y.N 4.Welilocatedinadefinedpool.................. ~'.' L //. - 5. Well located proper d~stance from drilling unit boundary~:*. . '. 4¡.14'j: -ft'tls ud( t:Vi/f.II¿ 6. Welll?cated proper d ~tanc~ fro~.other ~ells.. . . . . . . - . y, N Þov~;jj ~& '-í7é:<4,S 7. Sufficient acreage available In drilling Unit.. . . . . . . . . . . "N . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . ' N Y"'tt--5é ..s; 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N ~ 10. Operator has appropriate bond in force. . . . . . . . . . . . . 'N ~ ~vl0 C 11. Permit can be issued without conservation order. . . . . . . . .; N ~-í:u-'. ~.->j¿;r -ò 'J 12. Permit can be issued without administrative approval.. . . . . J N ';;'. . 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14.Conductorstringprovided................... YN~ ~ .- - 15. Surface casing protects all known USDWs. . . . . . . . . . . ,¡{Æ-"'f-tt-fL.- -r-I ( f ...f.1L-ì'.::;.'¡-Úrg t~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N 17. CMTvoladequatetotie-inlongstringtosurfcsg........ N Å" "- 18. CMTwili cover all known productive horizons. . . . . . . . . . N I-\'cVb~te e--t:. œC;, L...e.wc.. t"-'LA . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N - 21. If a re-drill, has a 10-403 for abandonment been approved. . . N . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N N1A 24. Drilling fluid program schematic & equip list adequate. . . . . $ N - 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ~, 26. BOPE press rating appropriate; test to 35'00 psig. N ~Asp:: . f 5: ( . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N ~,( bRl'O t..c..? 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y 00 ..¡-kJM. /ö.:Á . ~JUa4- ç/¿;U ~ ~.s ~ ,~~- ~ 31. Data presented on potential overpressure zones. . . . . . . ø. (/ /". . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. \ N A~Z DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . ..//IJ Y N ~2- 34. Contact name/phone for weekly progress reports [exp/~ry only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGŠ;~G: UIC/Annular: COMMISSION: RPC TEM ëJ-¡ ('--0") COT SFD . ~ WGA WCtk DTS , JMH d7l1 f-t ~ ~'2-- ENGINEERING APPR DATE i¡J(;,Â- ~ ~ J.{t -Dd GEOLOGY APPR DATE -- -- \ -' ) Y N Y N ;Jo WAit ~lc~ V d; ~ !2ð; lL. ( . I Comments/Instructions: :r!1 /6:J-- G: \geology\perm its \checklist, doc --f<'~~ \\\ ~ ,-" ~.}=- ~~ ~"\ 8($2 -0&3 . (jOI-ICZ59 ÐC@- DI9 g.o~ -O'{3 8°3 -o(s)3 UNOCAL8 UNOCAL ALASKA RESOURCES .~~ A-15RD, A-15RDST1, A-15RDST1L 1 & "~k\ A-15RDST1L1A- ~~9-Ld' TRADING SA Y UNIT Section 4- T9N-R13W-SM Cook Inlet, Alaska December 6, 2001 Brian O'Fallon - Sr. Logging Geologist Dick Ebright - Logging Geologist Barry Wright - Logging Geologist Michael Autra - Logging Geologist Mindaugas Kuzminskas - Logging Geologist ~ EPOCH r, /-', UNOCAL TABLE OF CONTENTS UNOCALALASKARESOURCES A-15RD, A-15RDST1, A-RDST1 L 1 & A-RDST1 L 1 A MIDDLE GROUND SHOAL COOK INLET, ALASKA TABLE OF CONTENTS .............................................................................................................."............1 WELL RESUME........................................................................................................................................2 LITHOLOGY AND COMMENTS................................................................................................................3 DAILY ACTIVITY SUMMARY......................................................................................,...........................50 SURVEY SUMMARY................................................""""""""""""""""""""""""""'"........................60 BEGIN SURVEY DATA FOR A 15RDST1 L 1A ..........................................................................................64 MUD SUMMARY ..........................................,....................,.....................................................................65 BIT RECORD................................................"""""""""""""""""""""""""""'".................................69 FI NAL LOGS...................................... """"""""""""""""""""""""'" ..........................."...... APPENDIX [~ EPOCH 1 Operator Well Name Field Region County State Coordinates Elevation API Index Spud Date Kick Off Point Casing Point Hole Size Total Depth Contractor Rig Tool Pushers Company Representatives Directional Company Personnel MWD Company Tools Personnel Epoch Personnel Mud Company Personnel ~ ,~, UNOCAL8 A-15RD WELL RESUME Unocal Alaska Resources A-15RD; A15RDST; A-15RDST1L1; A-15RDST1L1A Trading Bay Cook Inlet Kenai Borough Alaska Section 4, T9N, R13W SM 101' AMSL LO) / 1 "',7),)-),0/or-<'1 50-733-20254=01 ~-o - 1 3)-)..0 r 0)"'°;2./ )"0 -l.B - À.() II,) í"- (,0 > u- 12/06/2001 1074' MD 133/8" @ 1073' MD, 95/8" @ 8160' MD, 7" @ 12382'MD(ST1) 12.25" to' MD; 8.5" to 8160' MD, 6.0" to TD. A 15RD: 12428' MD (9830' TVD); A 15RDST: 13620' ,A-15RDST1 L 1: 13730', A- RDST1L 1A: 15042' Nabors Drilling Alaska Monopod Platform Ernie Sandidge, Rick Brumley, David Smith, Robert Kennedy Doug Niehaus, Shane Hauck Schlumberger Anadrill Mike Ward, Steve Watson Schlumberger Anadrill Real Time Gamma Ray Carlos Pacheco, Izwan Megat, Martin Perez-Valella Brian O'Fallon, Dick Ebright, Barry Wright, Michael Autra, Mindaugas Kuzminskas MI Drilling Fluids Mike Foreman, Monty Kanta, Keith Olson [~ EPOCH 2 ,~ r-"', UNOCAL8 A-15RD LITHOLOGY AND COMMENTS 1100 Coal = black to dusky brown; generally firm and brittle; dull to vitreous luster on fresh surfaces; slightly rough striated texture; occurs as irregular wedge and tabular shaped cuttings; grades to brown carbonaceous shale with soft woody texture; no visible bleeding gas. 1140 Claystone = light gray; moderately soluble washes out of sieve easily; non expansive; sticky mushy consistency; very smooth surface texture; dull luster; occurs as soft rounded lumps; rare laminations of shards and silt. 1190 Sand = very light gray; medium to fine grains; subangular; moderately well sorted in probable slight overall kaolic/ashy clay matrix; massive to thin interbeds of coal, tuffaceous claystone, and claystone; 80% quartz, and 20% black to brownish black and green grains, mostly hard; estimate mostly good porosity and permeability; no oil 1240 Coal = black to dark grayish brown to dark gray; subplaty to irregular fracture with some visible laminae; often scours dusky brown; massive thinly bedded lignite. 1270 Sand = medium light gray to light brownish gray; medium to fine and some coarse grains; subangular to angular; moderately to poorly sorted; 60% quartz, and 40% black to gray to green to light gray mostly partially siliceous lithics and possible epidote; slight to moderate clay matrix; estimate mostly fair to poor porosity and permeability; oil in mud, some intergranular stain and free oil spots; instant and streaming cut. SHOW NO.1: 1275-1350': SHOW NO.: 1 INTERVAL: 1275-1350' I FEET: 75 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 103 24 24 4822 0 0 0 0 AVERAGE: 195 16 100 21975 37 10 0 0 PEAK GAS: 207 15 152 33358 58 16 0 0 AFTER: 95 28 56 13335 39 2 0 0 1335 Sand = light gray; very fine to rarely grain; angular to sub rounded; moderate to well sorted; fair sphericity; 95% of sample is loose unconsolidated grains; trace of light clay matrix; non calc.; rare conglomerate of bit broken quartz; composed of 90% quartz, 10% igneous and metamorphic fragments, gray chert and trace epidote; infer fair to good in situ porosity; scattered brown pinpoint oil stains with weak fluorescence and very weak cut diminish to zero shows by 1350' (J EPOCH 3 ~ ~. UNOCAL8 A-15RD 1415 Sand = very light brown to light gray; very fine to fine grain; angular to subangular; moderately sorted; poor sphericity; generally unconsolidated; abundant brown clay matrix that washes out during cleaning leaving only loose grains; composed of 90% quartz, 10% chert, and dark lithic fragments; infer poor in situ porosity due to clay matrix; grades to argillaceous siltstone; rare brown pinpoint oil stains with even gold sample fluorescence and immediate pale yellow milky cut with rare streamers. Visible shows decrease to nil below 1460', 1495 Coal = black to very dark brown; hard to occasionally crumbly; rough surface texture; occurs as blocky to bladed cuttings; rare visible gas bubbles 1520 Sand = very light brown to light gray; very fine to fine grain; angular to subangular; moderately sorted; poor sphericity; generally unconsolidated; abundant brown clay matrix that washes out during cleaning leaving only loose grains; composed of 80% quartz, 20% chert, and dark lithic fragments; infer poor ¡nsitu porosity due to clay matrix; rare brown pinpoint oil stain confined to matrix cemented clusters 1490-1520, porosity inferred fair to good 1560-1625' due to absence of visible clay matrix; interval 1560-1625 has scattered to common brown pinpoint oil stain on individual sand grains; weak to moderate yellow gold sample fluorescence; immediate pale yellow cut fluorescence with occasional streamers. SHOW NO.2: 1560-1625': SHOW NO.: 2 INTERVAL: 1560-1625' I FEET: 65 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 154 29 24 5474 24 6 0 0 AVERAGE: 255 29 126 26378 182 100 50 0 PEAK GAS: 195 28 317 66192 453 249 124 0 AFTER: 43 10 10 1965 5 2 0 0 1620 Coal = black to grayish black to grayish brown; firm to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; lignite to subbituminous; massive to thinly interbedded with tuffaceous claystone, some carbonaceous shale and conglomerate. 1670 Sand = light gray to light brownish gray; fine to medium grains to slightly scattered coarse to pebble; angular to subangular; moderately to poorly sorted in slight ashy clay matrix grading upward to claystone; 75% quartz, and 25% mostly black carbonaceous and coal matter and minor light brown to green to white mostly igneous lithics; estimate mostly fair ~ EPOCH 4 -- ~ UNOCAL8 A-15RD to poor porosity; very rare brown oil spots; slight oil sheen and faint light yellow fluorescence with fair instantaneous milky cut 1745 Conglomeratic sand = light gray to very light brown; fine to medium grain with trace lower coarse; angular to subangular; poor to fair sorting; poor sphericity; 90% of sample is loose disaggregated grains; trace of cemented clusters in a light tan ashy matrix; composed of 90% quartz, 10% gray chert, dark igneous and metamorphic lithics; 20% of sample is freshly bit shattered pebbles; infer fair to good in situ porosity in cleaner zones; abundant brown oil stain on individual grains; even gold sample fluorescence; strong cut fluorescence with streamers; quality of oil shows decreases below 1820'. SHOW NO.3: 1764-1825': SHOW NO.: 3 I INTERVAL: 1764-1825' I FEET: 61 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 64 17 12 2302 34 25 8 0 AVERAGE: 121 10 71 15027 190 104 41 6 PEAK GAS: 187 17 106 24506 394 256 91 8 AFTER: 55 8 37 7669 66 35 14 0 1855 Tuffaceous claystone = white to light gray to light brown to brown; very soft and hydrophilic; sandy decreasing to smooth; some slightly to moderately organic mostly with carbonaceous matter but occasionally with oil stain and cut. 1890 Coal = grayish black to dark brownish gray; scours rusty brown; moderately firm with flaky to irregular fracture along bedding laminae; dull to slightly shiny luster; lignite; massive to thinly interbedded white to brown claystone; bleeding gas especially bedding planes. 1935 Coal = grayish black to dark brownish black; rough surface text; moderately firm with flaky to irregular fracture along bedding planes; dull to slightly shiny luster; lignite; massive to thinly interbedded white to brown claystone; common gas bubbles on cleat surfaces. 1975 Tuffaceous claystone = light gray to very light brown; soft and mushy when wet, firm and hard when dry; moderately soluble in water; gritty silty texture dull luster; common shards, mica and coal fragments; rare thin micro laminations of silt and fine grain sand. 2015 ~ EPOCH 5 ,~ ~ UNOCAL8 A-15RD Coal = grayish black to dark brownish black; rough surface text; moderately firm with flaky to irregular fracture along bedding laminae; dull to slightly shiny luster; lignite; massive to thinly interbedded white to brown claystone; common gas bubbles on clean surfaces. 2055 Tuffaceous claystone = light brownish gray; brittle and hard when dry; dull earthy luster, moderately soluble in water; occurs in sample as mushy rounded lumps; common micro lenses of black carbonaceous material, shards and silt; abundant inclusions of blocky coal fragments; grades to light gray kaolinitic clay and occasionally tuffaceous siltstone. 2125 Sand = light brown to light gray; very to fine grain; trace conglomerate of bit broken pebbles; angular to subrounded; moderately sorted; poor sphericity; composed of 80% quartz, 20% chert, feldspar, dark lithic fragments and coal fines; generally matrix support with tan to light gray clay matrix, probably kaolinite; non calcareous; grades to arenaceous, tuffaceous claystone and rare siltstone; very poor in situ porosity due to clay plugging; no visible oil shows fluorescence or cut. 2200 Sand = light brown; very fine to medium grains; angular to subrounded; poor sorting and sphericity; 20-30% of sample is bit shattered conglomerate pebbles; sand is composed of 70% quartz. 30% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 80% loose grains with scattered cemented clusters in a white clay matrix; infer fair to good in situ porosity; common even brown oil stain; even gold fluorescence; immediate yellow cut with streamers. SHOW NO.4: 2195-2225': SHOW NO.: 4 ¡INTERVAL: 2195-2225' I FEET: 30 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 47 4 25 5137 35 14 7 0 AVERAGE: 89 10 67 13940 120 49 79 0 PEAK GAS: 72 7 98 20673 158 54 87 0 AFTER: 52 22 18 3467 34 17 21 0 2270 Tuffaceous claystone = light brownish gray; brittle and hard when dry; dull earthy luster, moderately soluble in water; occurs in sample as mushy rounded lumps; common micro lenses of black carbonaceous material, shards and silt; abundant inclusions of blocky coal fragments; grades to light gray kaolinitic clay and is interbedded with fissile carbonaceous shale 2325 (;I EPOCH 6 ~ ~ UNOCAL8 A-15RD Sand = light brown; very fine to medium grain; angular to sub rounded; poor sorting and sphericity; 10-20% of sample is bit shattered conglomerate pebbles; sand is composed of 70% quartz. 30% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 70% loose grains with scattered cemented clusters in a white clay matrix; infer fair to good porosity; fair even oil sheen in washed sample with dull yellow gold even fluorescence on sand grains; occasional visible light to medium brown stain; instantaneous light yellow milky to diffuse cut. SHOW NO.5: 2325-2400': SHOW NO.: 5 ¡INTERVAL: 2325-2400' I FEET: 75 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 101 29 25 4819 47 14 7 2 AVERAGE: 130 24 191 34790 506 204 158 38 PEAK GAS: 133 24 375 68461 1023 409 293 95 AFTER: 102 30 48 8949 130 52 65 8 2415 Coal = grayish black to dark brownish gray; moderately brittle to slightly crumbly; irregular to subplaty fracture, with some visible laminae;scours rusty brown on crumbly surfaces; lignite to some subbituminous; very slight isolated micropyrite specs; massive to interbeds of carbonaceous to tuffaceous claystone and some sand; very faint to faint oil sheen in washed sample; slight cut 2410-30' diminishing to trace cut 2430-50'. 2475 Tuffaceous claystone = very light gray to some light brownish gray to brown; hydrophilic; slight to moderate gritty/silty texture; slight disseminated to flaky carbonaceous matter; occasionally grading to carbonaceous shale with thin coal streaks and interbedded coal; some sandy grading sand with angular medium to fine and scattered coarse to pebble grains; slight oil sheen and faint yellow gold fluorescence; slight instantaneous and slight slow streaming cut. 2540 Tuffaceous claystone = very light gray to some light brownish gray to trace brown; hydrophilic; slightly to some moderately gritty/silty texture; occasionally grading carbonaceous shale with thin coal streaks; occasionally grading sand; no visible oil sheen and no cut 2580 Sand = light gray to very light gray; fine to medium and scattered coarse to locally scattered pebble grains; subangular; moderate sphericity; mostly loose grains in white to slightly organic light brownish gray kaolic/ashy matrix; rare well consolidated and dense in calcareous cement; 80% quartz, and 20% black to brown to gray to green to red lithics including coal and carbonaceous clay, possibly epidote and feldspar, and minor chert increasing in conglomeratic fraction; estimate mostly fair to poor porosity and permeability; no oil sheen or cut. [j EPOCH 7 ~ ~ UNOCAL8 A-15RD 2660 Coal = grayish black to brownish black; often scours rusty brown; moderately brittle to crunchy; irregular to subplaty fracture; lignite to some subbituminous; massive to thin beds and clasts in carbonaceous claystone; very slight micropyrite specs; bleeding gas. 2700 Tuffaceous claystone = light gray to light brownish gray to very light gray; tuffaceous claystone = light gray to light brownish gray to very light gray; hydrophilic; smooth to moderately silty/gritty texture; mostly slightly organic including carbonaceous flakes; some grading carbonaceous shale increasingly organic with thin carbonaceous partings and coal streaks; possible thin interbeds of clayey sands and silt; slightly scattered chert pebbles. 2765 Coal = brownish black to grayish black; often scours rusty brown; crunchy to moderately brittle; irregular to subplaty fracture; lignite; thinly bedded in slightly organic tuffaceous claystone and minor carbonaceous shale; very slight micropyrite; slight bleeding gas. 2805 Sand = light gray to light brownish gray; very fine to medium grains and slightly scattered coarse to trace pebble; angular to subangular; moderate to high sphericity; moderately sorted in slight to moderate clay matrix; 75% quartz, and 25% black to gray to rust to tan to red mostly coal, carbonaceous, and clay lithics and minor feldspar; estimate mostly fair porosity and permeability; slight oil sheen and faint odor; trace visible brown oil stain on sand grains; slight instantaneous milky cut to slow diffuse light yellow gold cut diminishing slightly in 2870-2900' sample. SHOW NO.6: 2805-2900': SHOW NO.: 6 ¡INTERVAL: 2805-2900' I FEET: 95 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) CPPM) IPPM) IPPM) (PPM) (PPM) BEFORE: 88 28 24 4784 92 31 12 0 AVERAGE: 142 28 65 11965 377 191 106 21 PEAK GAS: 121 18 116 21366 602 340 202 50 AFTER: 100 32 37 6453 225 95 51 8 2890 Sand = light brown to light gray; very fine grain; trace conglomerate of bit broken pebbles; angular to subrounded; moderately sorted; poor sphericity; composed of 80% quartz, 20% chert, feldspar, dark lithic fragments and coal fines; generally matrix support with very light gray mushy clay matrix, probably kaolinite; non calcareous; grades to arenaceous, tuffaceous claystone and rare siltstone; very poor in situ porosity due to clay plugging; no visible oil shows, 2960 ~ EPOCH 8 ,.-., ~ UNOCALe A-15RD Coal = grayish black to dark brownish black; rough surface text; moderately firm with flaky to irregular fracture along bedding planes; dull to slightly shiny luster; lignite; massive to thinly interbedded white to brown claystone; common gas bubbles on clean surfaces. 3000 Sand = light brown; very fine to fine grain; angular to sub angular; poor sorting and sphericity; 10% of sample is bit shattered conglomerate pebbles; sand is composed of 90% quartz. 10% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is +90% loose grains with scattered cemented clusters in a white clay matrix; infer fair to good porosity; even gold sample fluorescence; common brown oil stain on about 50% of grains; immediate milky cut without streamers; quality of oil shows decreases below 3050' SHOW NO.7: 2985-3055': SHOW NO.: 7 I INTERVAL: 2985-3055" I FEET: 70 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 75 29 63 11550 281 179 244 6 AVERAGE: 92 26 86 15525 353 214 225 32 PEAK GAS: 92 27 162 30957 412 258 365 58 AFTER: 77 27 45 8670 123 82 101 20 3080 Coal = grayish black to dark brownish black; rough surface text; moderately firm with flaky to irregular fracture along bedding planes; dull to slightly shiny luster; lignite; massive to thinly interbedded white to brown claystone and commonly brown organic rich carbonaceous shale with occasional woody plant remains. 3130 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy, runny consistency; gritty, silty texture; dull luster when dry; occurs as soft mushy lumps in sample; abundant silt, shards, sand and conglomerate pebbles; becomes an argillaceous sand in part; common detrital coal fines; common even light gold fluorescence from clay; very rare visible brown oil spots; very weak light yellow milky cut 3205 Sand = light brown; very fine to fine grain; angular to subangular; fair sorting and sphericity; 10% of sample is bit shattered conglomerate pebbles; sand is composed of 90% quartz. 10% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 80% loose grains with scattered cemented clusters in a minimal clay matrix; infer fair to good in situ porosity; even light yellow to gold sample fluorescence; approx. 20% of sample has a light brown oil stain on individual grains; immediate [~ EPOCH 9 ,~ ~ UNOCAL8 A-15RD strong milky cut without streamers; quality of shows decreases downward from 3235'. SHOW NO.8: 3180-3260': SHOW NO.: 8 1 INTERVAL: 3180-3260' I FEET: 80 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) CPPM) CPPM) (PPM) (PPM) BEFORE: 39 32 63 i0473 264 196 205 49 AVERAGE: 82 26 97 15004 465 394 396 153 PEAK GAS: 114 29 158 24107 778 630 606 260 AFTER: 79 24 44 5613 180 167 198 98 3300 Conglomeratic sand = light gray overall; fine to medium grains and slight to moderate coarse grains and pebbles; finer fraction subangular, 80% quartz, and 20% black to minor gray, red, and green including mostly coal and carbonaceous lithics and minor feldspar; coarser fraction mostly chert and siliceous metalithics and lithics; overall poorly sorted and matrix supported in clay grading claystone and conglomerate; estimate mostly poor to possible fair porosity; no visible oil or fluorescence; slight instant to diffuse cut and faint residue. 3380 Tuffaceous claystone = light brownish gray to some grayish brown; soft and hydrophilic; slightly silty texture; locally with floating pebbles and slightly sandy; mostly slightly organic including disseminated carbonaceous matter; some flaky carbonaceous matter and coal streaks occasionally grading to carbonaceous shale. 3430 Coal = grayish black to brownish black; slightly finn to firm; irregular to subplaty fracture; lignite to subbituminous massive; slight micropyrite specs. 3455 Sand = light brownish gray from 3430-3470' to mostly very light gray to white lower; medium to very fine grains and scattered coarse; moderately to poorly sorted in ashy, kaolic, and variably organic clay; estimate mostly grain supported; some grading to interbedded claystone, carbonaceous claystone and thin coal; 75% quartz, and 25% mostly black to brown carbonaceous lithics and some green to red to gray partially siliceous lithics; estimate mostly fair to poor porosity and permeability; no odor, or visible stain and fluorescence; very slight instantaneous to diffuse milky cut and weak residue 3475- 3500'. 3540 Coal = grayish black to black to brownish black; finn to slightly firm and moderately brittle to crunchy; irregular to subplaty fracture; subbituminous to lignite; mostly massive to some ~ EPOCH 10 .~ ~ UNOCAL8 A-15RD with clay partings and grading to and interbedded with carbonaceous and tuffaceous claystone; slight bleeding gas; some sand and conglomerate at base with a faint diffuse light yellow cut 3580-94'. 3595 Tuffaceous claystone = very light gray to light brownish gray to occasionally grayish brown; soft and hydrophilic; mostly very slightly to some moderately organic including carbonaceous specs and flakes grading carbonaceous shale with slight coal clasts and streaks; slightly sandy overall including occasional floating coarse grains and pebbles. 3645 Sand = light gray to very light gray; very fine to coarse grains and locally scattered pebbles; angular to subangular including fragments; moderately to poorly sorted in probable slight overall clay matrix; 70% quartz, and 30% black to brown to tan to red to gray grains including siliceous igneous, metalithics and lithics; estimate mostly fair to some good porosity and permeability; no visible oil stain; slight odor and sheen; even light yellow fluorescence; slight to moderate light yellow cut. SHOW NO.9: 3634-3760': SHOW NO.: 9 I INTERVAL: 3634-3760' I FEET: 126 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 28 13 7 1073 35 34 19 4 AVERAGE: 158 21 118 16620 858 942 603 246 PEAK GAS: 195 20 220 31215 1687 1818 1131 413 AFTER: 71 18 32 4405 198 224 180 84 3715 Carbonaceous shale = grayish brown to light brownish gray; soft and hydrophilic; amorphous to slightly flaky; moderately to slightly organic including disseminated matter and flakes and very thin partings of carbonaceous matter; some thin coal streaks and beds; locally sandy to conglomeratic especially grading tuffaceous claystone and sand. 3775 Sand = light brown; very fine to fine grain; angular to sub rounded; fair sorting and sphericity; 5% of sample is bit broken chert and quartz pebbles; sand is composed of 90% quartz, 10% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 90% loose grains with scattered cemented clusters in a light gray clay matrix; infer fair to good in situ porosity; sand from 3780-3800 is abundantly clay packed with poor porosity; even light gold sample fluorescence, very slow milky cut; less than 5% of sample has visible brown oil stain on individual sand grains; rainbow oil sheen visible on washed sample. SHOW NO. 10: -3800-3850': I SHOW NO.: I 10 I INTERVAL: I 3800-3850' D FEET: I 50 I ~ EPOCH 11 - ~ UNOCAL8 A-15RD ROP woe GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 115 28 156 26457 721 730 600 247 AVERAGE: 114 31 183 29557 863 874 696 290 PEAK GAS: 166 28 375 63370 1757 1740 1383 569 AFTER: 24 23 46 6529 213 222 178 86 3865 Sand = light brown; very fine to fine grain; angular to sub rounded; fair sorting and sphericity; 5- 10% of sample is bit broken chert and quartz pebbles; sand is composed of 90% quartz. 10% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 90% loose grains with scattered cemented clusters in a light gray ashy clay matrix, probably kaolinite; estimate mostly fair to good in situ porosity; even light gold sample fluorescence, very slow milky cut; less than 5% of sample has visible brown oil stain on individual sand grains; rainbow oil sheen visible on washed sample. SHOW NO. 11: 3880-4090': SHOW NO.: 11 ¡INTERVAL: 3880-4090' I FEET: 210 ROP woe GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 69 25 89 13408 354 346 287 156 AVERAGE: 84 14 215 32325 1024 1022 789 432 PEAK GAS: 124 16 566 78712 2676 2720 2060 1039 AFTER: 14 7 39 4102 128 137 98 109 3950 Sand = light brown; very fine to fine grain; angular to sub rounded; fair sorting and sphericity; 15-2% of sample is bit broken chert and quartz pebbles; sand is composed of 90% quartz. 10% chert, feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 90% loose grains with scattered cemented clusters in a light gray ashy clay matrix, probably kaolinite; estimate mostly fair to good in situ porosity; even light gold sample fluorescence, moderate milky cut; 5-10% of sample has visible brown oil stain on individual sand grains; rainbow oil sheen visible on washed sample. 4035 Conglomerate (4040-4055) = light gray; very coarse to pebble size; well rounded frosted grain surfaces; moderately consolidated; clasts are in a light gray to white kaolinitic, ashy, clay matrix with abundant sand and silt size grains; pebbles are composed of quartz, chert, quartzite, slate, and dark igneous and metamorphic lithics 95% bit broken; scattered visible brown oil stain confined to matrix material; variable mineral fluorescence; slow milky cut; oil sheen visible on washed sample. 4110 [~ EPOCH 12 .- ~ UNOCAL8 A-15RD Coal = grayish black to brownish black; slightly firm to firm; crunchy to some slightly brittle; common visible lamina hard to soft packed with hackly to flaky fracture; lignite to subbitumínous with some thin carbonaceous clay partings. 4145 Sand = light olive gray to very light gray; coarse lower to very fine grains especially medium to fine, and slightly scattered coarse to locally pebbles; subangular to angular to locally subrounded; moderately to some poorly sorted in overall slight kaolic clay matrix locally grading kaolic/ashy tuff; 70-80% quartz, and 20-30% black to dark gray to tan to minor red, bluish gray, and green including partially siliceous coal, clay, and tuff clasts, metalithics and chert, and feldspar, with chert increasing in conglomeratic fraction; estimate mostly fair to locally good porosity and permeability; slight spotty oil stain; faint to fair odor; fair oil sheen in mud; slight to faint oil sheen on washed sample with dull to moderate yellow gold fluorescence and cut. SHOW NO. 12: 4135-4209': SHOW NO.: 12 I INTERVAL: 41354209' I FEET: 84 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 12 3.8 47 5809 114 86 76 88 AVERAGE: 46 6.1 243 35445 1022 1078 773 461 PEAK GAS: 40 6.9 529 73237 2228 2338 1720 1090 AFTER: SHOW #13 4250 Conglomeratic sand = light olive gray to medium light gray; very fine to pebbles and fragments; subangular to angular; mostly loose grains in sample to occasional well consolidated with rare hard packed siliceous to slightly calcareous clay cement to occasional loosely consolidated in white to light brownish gray clay; 40% quartz, and 60% black to tan to bluish gray to white to green to red grains including chert, metalithics including sandstone pebbles, partially siliceous lithics and tuffs, and minor feldspar; estimate variable porosity and permeability from very poor to occasionally good; fair oil sheen in mud and faint to fair oil sheen in washed sample; fair to faint odor; some spotty stain on grains and hard clays; slight even light yellow fluorescence overall with some moderate on individual grains and hard clay matrix; fair instantaneous overall cut with some slow streams to diffuse. SHOW NO. 13: 4210-4365': SHOW NO.: 13 /INTERVAL: 4210-4365' I FEET: 155 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KlBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: SHOW #12 AVERAGE: 63 4.6 341 46200 1441 1690 1522 837 PEAK GAS: 51 1.2 62 86067 2720 3085 2653 1421 AFTER: 1.2 4.3 48 1059 61 96 228 309 4395 r;t EPOCH 13 --- ~ UNOCAL8 A-15RD Sand = light brown; very fine to fine grain; angular to sub rounded; fair sorting, mod. Sphericity; rare angular bit broken chert and quartz pebbles; sand is 90% quartz, 10% gray to black chert, pink feldspar, dark igneous and metamorphic fragments, mica and rare coal fines; sample is 90% loose grains with rare weakly indurated clusters in a light gray calcareous clay matrix; infer fair to good in situ porosity; no visible oil stain; even, weak, light gold sample fluorescence, very weak, pale yellow, diffuse cut without streamers. 4475 Coal = dark gray to grayish black to brownish black; slightly firm to firm to occasionally hard; mostly crumbly to moderately brittle; flaky to irregular fracture; lignite to occasionally subbituminous; hard coals siliceous and probably reworked as clasts in conglomeratic clays and sands; massive to occasionally grading brown carbonaceous shale. 4530 Tuffaceous claystone = light gray to light bluish gray to very light gray to grayish brown; soft and slightly to moderately hydrophilic; smooth to silty/sandy and scattered pebbles; occasional carbonaceous with coal streaks. 4565 Conglomeratic sand = medium light gray to light bluish gray; very fine to some coarse and pebbles; angular to subangular; poorly to moderately sorted in variable clay matrix some grading to siltstone, claystone, and conglomerate; 75% quartz, and 25% mostly black partially siliceous coal to some grayish chert and partially siliceous tan, red and green lithics; estimate fair to poor porosity decreasing grading clay; faint to slight light yellow fluorescence and sheen; trace visible light brown to brown spotty oil stain; trace diffuse cut except fair cut 4550-70'. SHOW NO. 14: 4545-4615': SHOW NO.: 14 I INTERVAL: 4545-4615 I FEET: 70 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) lPPM) (PPM) lPPM) lPPM) BEFORE: 22 30 18 2035 56 74 105 44 AVERAGE: 53 28 131 19660 460 443 439 193 PEAK GAS: 69 29 186 29330 662 585 533 220 AFTER: 23 29 55 7331 186 206 228 81 4645 Coal = grayish black to brownish black; slightly firm to firm; crunchy to moderately brittle; hackly to subplanar fracture; lignite; massive to rare grading carbonaceous shale. SHOW NO. 15:4650-5152': 4675 Sand = medium light gray to occasionally very light gray to light brownish gray; very fine to coarse and locally slight pebble, mostly medium to fine fast drilling; subrounded to ~ EPOCH 14 -. ~. UNOCAL8 A-15RD angular; moderately to poorly sorted; mostly very slight clay matrix; some clayey with probable thin clay zones; 70-80% quartz, and 20-30% mostly black to minor tan, gray, red and green partially siliceous and chert; estimate mostly good to fair porosity; very faint sheen and overall slight to fair even light yellow fluorescence with slight instantaneous to diffuse cut. SHOW NO.: 15A ¡INTERVAL: 4650-4750' I FEET: 100 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 14 20 30 3631 100 130 171 68 AVERAGE: 76 17 461 73178 983 790 820 433 PEAK GAS: 107 21 894 143714 1982 1513 1520 802 AFTER: 41 10 209 35284 411 333 393 244 4760 Sand = light gray to light brownish gray; fine to medium grain to occasionally coarse grain; subangular to rarely rounded; poorly sorted; fair to high sphericity in rounded fraction; about 20 % of sample is well rounded pebbles of mostly gray to black chert and some quartz and dark lithics; overall sample is 70% quartz, 30% gray chert, feldspar, dark igneous and metamorphic lithic fragments, slate, mica and rare coal fines; sample is over 90% loose grains; rare clusters in a light gray clay matrix; estimate fair to good in situ porosity especially in cleaner zones; no visible oil stain; even, weak, light gold sample fluorescence, very weak, pale yellow, diffuse cut without streamers; weak light yellow ring fluorescence; faint sheen visible on washed sample. SHOW NO.: 15B !INTERVAL: 4751-4860' I FEET: 109 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 41 10 209 35284 411 333 393 244 AVERAGE: 104 18 352 60411 646 460 553 317 PEAK GAS: 189 30 597 108090 1133 748 867 518 AFTER: 150 29 268 45412 442 296 375 224 4865 Sand = light gray to light brownish gray; fine to medium grain to occasionally coarse grain; subangular to rarely rounded; poorly sorted; fair to high sphericity in rounded fraction; about 20 % of sample is well rounded pebbles of mostly gray to black chert and some quartz and dark lithics many broken by bit shearing; overall sample consists of 70% quartz, 30% gray chert, feldspar, dark igneous and metamorphic lithic fragments, slate, mica and rare coal fines; sample is over 90% loose grains; rare clusters in a light gray clay matrix; estimate fair to good in situ porosity especially in cleaner zones; no visible oil stain; even, weak light gold sample fluorescence, very weak, pale yellow, diffuse cut without streamers; weak light yellow ring fluorescence; faint sheen visible on washed sample. SHOW NO.: 15C I INTERVAL: 4861-4965' I FEET: 104 ROP WOB GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 150 29 268 45412 442 296 375 224 AVERAGE: 136 22 474 77601 734 459 550 308 [:I EPOCH 15 .~ r'-, UNOCAL8 A-15RD PEAK GAS: AFTER: 103747 41926 4975 Sand = light gray to light brownish gray; fine to medium grain to occasionally coarse grain; subangular to rarely rounded; poorly sorted; fair to high sphericity in rounded fraction; 10-20 % of sample is rounded pebbles of mostly gray to black chert and some quartz and dark lithics, many broken by bit action; overall sample consists of 70% quartz, 30% gray chert, feldspar, dark igneous and metamorphic lithic fragments, slate, mica and rare coal fines; sample is over 90% loose grains; rare clusters in a light gray soluble calcareous clay matrix that washes out of sieve easily; no oil stain; weak light yellow sample fluorescence; very weak slow diffuse milky cut that leaves a faint yellow fluorescent ring; trace faint rainbow oil sheen on washed sample. SHOW NO.: 15D I INTERVAL: 4966-5080' I FEET: 114 ROP woe GAS C1 C2 C3 C4 C5 (FT/HR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 30 20 281 41926 372 226 303 227 AVERAGE: 103 23 336 57303 453 252 381 263 PEAK GAS: 85 20 547 95800 700 345 540 353 AFTER: 126 28 254 42916 305 141 229 148 5100 Conglomeratic sand=light gray to light brownish gray; conglomerate fraction is very coarse to pebble size; well rounded frosted grain surfaces; moderately consolidated; clasts are in a light gray to white kaolinitic, ashy, clay matrix with abundant sand and silt size grains; pebbles are composed of quartz, chert, quartzite, slate, and dark igneous and metamorphic lithics, 90% are bit broken; sand fraction is light to very light gray; fine to lower medium grain; angular to subangular; fair sorting; poor sphericity; composed of 70% quartz, 30% black chert and abundant dark igneous and metamorphic fragments; sample is +95% loose grains; rare soluble clay matrix that washes out of sieve during washing; no visible oil stain; no fluorescence; extremely weak diffuse cut; no sheen on washed sample. SHOW NO.: 15E ¡INTERVAL: 5081-5152' I FEET: 71 ROP woe GAS C1 C2 C3 C4 C5 (FTlHR) (KLBS) (UNITS) (PPM) (PPM) (PPM) (PPM) (PPM) BEFORE: 126 28 254 42916 305 141 229 148 AVERAGE: 89 20 294 52629 375 176 293 206 PEAK GAS: 140 28 462 77870 550 254 417 286 AFTER: 38 23 36 5098 39 26 55 42 5210 Conglomerate = light gray to brownish gray; coarse to pebble size; rounded frosted grain surfaces; moderately consolidated; rare clasts are in a gray to white kaolinitic, ashy, clay matrix with abundant sand, silt and shards; pebbles are composed of quartz, chert, quartzite, slate, and dark igneous and metamorphic lithics, most are bit broken sample is [~ EPOCH 16 ,-... ~, UNOCAL8 A-15RD mostly loose disaggregated grains and broken pebbles with no visible cement or matrix; no visible oil stain; no fluorescence; no cut. 5285 Coal = black to grayish black; very firm and slightly brittle to slightly firm and crunchy; irregular subblocky to subplaty and flaky fracture; moderately shiny to dull luster; dense to laminar; bituminous to lignite; mostly massive; some thin beds and clasts in carbonaceous shale and occasionally hard and siliceous probably reworked as clasts in conglomeratic sand and conglomerate. 5340 Conglomeratic sand = medium light gray; medium to fine to scattered coarse and pebble grains; subangular to subrounded; moderately to some poorly sorted; estimate slight overall clay matrix; 80% quartz and 20% mostly black to some gray to red to green partially siliceous lithics; estimate mostly fair to some good porosity and permeability; trace to no fluorescence or cut. 5395 Coal = grayish black to brownish black to black; very firm and slightly brittle to slightly firm and crunchy; irregular subplaty to irregular subblocky fracture; lignite to occasionally bituminous; massive to grading to carbonaceous shale. 5430 Conglomeratic sand = medium gray to medium light gray; coarse grains and pebbles to fine grains; subangular to angular; poorly to some moderately sorted in overall slight clay matrix and possible thin beds grading claystone and conglomerate; 50% quartz and 50% mostly black to some gray to white to minor tan, red, and green including metalithics and chert, and partially siliceous lithics; estimate mostly fair to poor porosity and permeability; some spotty dull fluorescence and trace visible oil stain; trace instantaneous to diffuse cut. 5510 Conglomeratic sand = medium gray to medium light gray; fine to coarse grains and pebbles; subangular to angular; poorly to some moderately sorted in overall slight clay matrix and possible thin beds grading claystone, coal, and conglomerate; 50% quartz, and 50% mostly black to some gray to white to minor tan, red, and green including metalithics and chert, and partially siliceous lithics; estimate mostly fair to poor porosity and permeability; some dull old fluorescence on isolated grains; very slight diffuse cut. 5585 Conglomerate = brownish gray to medium gray; pebbles and fragments to some coarse to fine grains; poorly sorted grading downward to white to light gray tuffaceous and brownish gray carbonaceous claystone. 5620 [~ EPOCH 17 ---. ~. UNOCAL8 A-15RD Coal = brownish black to grayish black to black; very firm and slightly brittle to slightly firm and crunchy; irregular hackly to subplaty fracture; dense and moderately shiny to laminar and dull to earthy with organic clay partings; mostly massive lignite to some bituminous to grading carbonaceous shale with thin coal partings. 5670 Tuffaceous claystone = light brownish gray; very soluble to soluble; gritty/silty to smooth texture; lightly speckled dark carbonaceous matter in slight organic clays; trace micas; grading clayey sandstone with angular very fine to fine grains and silt; trace disseminated micas 5715 Sand = light gray to light brownish gray; very fine to medium grains, mostly fine; angular; moderately to poorly sorted mostly grain supported in clay matrix; clays mostly very slightly to slightly organic; 75-85% quartz, 10-15% coal and carbonaceous speckles, and 5% gray, red, green and white lithics; trace to slight floating pebbles; estimate poor to fair porosity and permeability due to clay infilling; no fluorescence or cut. 5780 Sand = medium light gray; very fine to coarse, especially medium to fine, and locally scattered pebbles; angular to subangular; moderate sphericity; moderately sorted in overall slight clay matrix; possible thin zones clay and conglomerate; 85% quartz, and 15% black to dark brown to white to tan mostly coal and carbonaceous lithics, slight calcareous matter and other lithics; estimate mostly fair porosity and permeability; no oil indicators. 5845 Sand = light gray to medium light gray; very fine to coarse especially fine to coarse lower, and locally scattered pebbles; subangular to angular; estimate moderately to some poorly sorted in overall slight clay matrix; 85% quartz and 15% black to gray to brown to green partially siliceous lithics, metalithics chert, and calcareous matter; estimate mostly fair porosity and permeability; no oil indicators. 5905 Sand = light gray to medium light gray; very fine to coarse especially fine to coarse lower, and locally scattered pebbles; subangular to angular; estimate moderately to some poorly sorted in overall slight clay matrix; probable thin beds tuffaceous claystone and tuff; 85% quartz, 15% black to gray to brown to green partially siliceous lithics, metalithics, chert, and calcareous matter; estimate mostly fair porosity and permeability; no oil indicators. 5975 Coal = black to grayish black to grayish brown; firm to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; lignite to sub bituminous; occasional thin interbeds of dark brown, fissile carbonaceous shale and conglomerate; common rough, striated surfaces; blocky to tabular habit; common bleeding gas bubbles on clean surfaces and bedding planes. [;I EPOCH 18 --., .--- UNOCALe A-15RD 6030 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy, runny consistency; gritty, silty texture; dull luster when dry; occurs as soft mushy lumps in sample; abundant silt, shards, sand and conglomerate pebbles; grades to an argillaceous sand in part; common detrital coal fines and black to brown specks of organic material; abundant bladed coal cavings. 6085 Tuffaceous claystone = very light gray to light brown; moderately soluble in water washes out of sieve readily leaving.a residue of sand, pebbles and shards; mushy, runny consistency; gritty, silty texture; dull luster when dry; occurs as soft mushy lumps in sample; abundant silt, shards, sand and conglomerate pebbles embedded in the clay matrix; grades to an argillaceous sand in part; common detrital coal fines and black to brown specks of organic material; common coal cavings. 6170 Coal = black to grayish black to grayish brown; firm to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; lignite to sub bituminous; occasional thin interbeds of dark brown, fissile carbonaceous shale and conglomerate; common rough, striated surfaces; blocky to tabular habit; common bleeding gas bubbles on clean surfaces and bedding planes. 6225 Conglomerate = light to medium gray; very coarse to pebble size; well rounded frosted grain surfaces; moderately consolidated; rare clasts are in a gray to white kaolinitic, ashy, clay matrix with abundant sand and silt size grains; pebbles are composed of quartz, chert, quartzite, slate, and dark igneous and metamorphic lithics 95% bit broken; no visible oil indicators. /' 6285 Sand = medium light gray; very fine to coarse grains, especially medium to fine and trace very coarse to pebble; angular to subangular; moderately sorted in overall very slight clay matrix; 85% quartz, and 15% mostly black to dark gray metalithics and partially siliceous lithics including coal fines, and minor white, tan, red, and green including calcareous matter; estimate mostly fair porosity and permeability; no hydrocarbon indicators. 6350 Tuffaceous claystone = very light gray to white to occasionally brownish gray; hydrophilic except occasionally firm and calcareous; slightly to moderately silty/gritty texture with mostly angular silts and fine grains to occasional floating coarse and pebble sized phenocrysts; occasionally organic commonly associated with coal streaks. 6400 (J EPOCH 19 ,,-.., ,-... UNOCAL8 A-15RD Tuffaceous claystone = medium light gray to light brownish gray; hydrophilic; slight to moderate silty/fine sandy texture with slightly scattered larger grains; overall slight to very slightly organic; slight carbonaceous matter and coal; slight disseminated calcareous matter. 6445 Sand = medium light gray; very fine to medium grains and scattered coarse to trace pebble; angular; moderate sphericity; moderately sorted in overall slight clay matrix; some sandstone with calcareous cement; 85% quartz, and 15% black to gray to brown to tan to white to red to green partially siliceous lithics and metalithics and chert; estimate fair to some poor porosity and permeability; no oil indicators. 6505 Tuffaceous claystone = medium light gray to light brownish gray; soft and soluble; smooth to silty texture; often sandy as sand cavings wash into soluble clays; slightly organic; slight coal and carbonaceous matter; possible thin coal streaks locally; slight calcareous matter. 6550 Tuffaceous claystone = light brownish gray to medium light gray; soft to occasionally slightly firm; smooth to some silty texture; some sandy texture, in part do to sloughing sands absorbed into hydrophilic clays; slightly organic with locally coal partings and thin beds and occasionally grading to carbonaceous shale; trace calcite. 6605 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy, runny consistency; gritty, silty texture; dull luster when dry; occurs as soft mushy lumps in sample; common silt, shards, sand and conglomerate pebbles; grades to an argillaceous sand in part; common detrital coal fines and black to brown specks of organic material; thin interbeds of coal and especially dark brown, fissile carbonaceous shale; rare thin interlaminations of pebble conglomerate. 6675 Tuffaceous claystone = very light gray to light brown; moderately soluble in water; mushy to somewhat firm; gritty, silty texture; dull luster when dry; occurs as soft runny lumps in sample; common shards, sand and silt embedded in matrix; grades to an argillaceous sand in part; common detrital coal fines and black to brown specks of organic material; thin interbeds of coal and especially dark brown, fissile carbonaceous shale; rare thin interlaminations of pebble conglomerate. 6760 Coal = black to grayish black to grayish brown; finn to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; lignite to sub bituminous; occasional thin interbeds of dark brown, fissile carbonaceous shale and conglomerate; common rough, striated surfaces; blocky to tabular habit; common bleeding gas bubbles on clean surfaces and bedding planes. ~ EPOCH 20 ~ ~ UNOCALe A-15RD 6815 Coal = black to grayish black to grayish brown; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; appears sub bituminous; occasional thin interbeds of dark brown, fissile carbonaceous shale and conglomerate; common rough, striated surfaces with conchoidal fracture; bladed to blocky cuttings habit; common bleeding gas on bedding planes. 6880 Tuffaceous claystone = very light gray to medium light gray to light brownish gray; soft and mushy and hydrophilic; smooth to some silty/fine sandy texture; slight disseminated coal fines especially silty; often grading carbonaceous shale associated with coal partings and thin beds; some slightly to moderately calcareous including calcite. 6930 Carbonaceous shale = grayish brown to light brownish gray; soft to moderately soft to occasionally slightly firm; moderately hydrophilic; amorphous to subplaty to flaky; moderately to slightly organic; slight to moderate carbonaceous matter loosely scattered to subplanar flakes and partings along laminations; streaks and thin beds coal. 6980 Sand = light gray to very light gray; very fine to medium, especially fine to medium, and scattered coarse to trace pebble; angular to subangular; moderate sphericity; estimate mostly very slight to locally moderate kaolic clay matrix; moderately sorted overall; 80% quartz, and 20% mostly black to brown coal and clay lithics, siliceous in part; estimate fair porosity and permeability; no oil indicators. 7045 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; rough striated surfaces with conchoidal to hackly fracture; tabular to irregular cuttings habit; thin interbeds of dark brown fissile carbonaceous shale; rare very thin sand laminations on partings; no visible bleeding gas. 7100 Sand = light gray to light brownish gray; very fine to fine grain to rarely lower medium grain; angular to sub angular; moderate to well sorted; moderate sphericity in most of sample; nearly 100% of sample is loose, unconsolidated grains with no visible cement or matrix; estimate slight soluble clay matrix that is removed during sample washing; sample is +90% quartz with minor chert and dark igneous and metamorphic fragments; estimate fair to good in situ porosity; no oil stain; no fluorescence; no cut. 7190 Sand = light gray to medium light gray; very fine to coarse, especially fine to medium grains; angular to subangular; moderately sorted; loose grains commonly lightly frosted white calcareous cement and trace sandstone clusters with calcareous cement; probable ~ EPOCH 21 ~ ~ UNOCAL8 A-15RD some slight clay matrix; 80% quartz, and 20% mostly coal and clay and minor other lithics; estimate poor to fair porosity and permeability; no oil indicators. 7255 Coal = brownish black to black; firm to moderately firm; moderately to slightly brittle; hackly to subplaty to bladed, fracture; slightly shiny to dull luster; subbituminous to lignite; massive to occasionally grading carbonaceous shale. 7290 Tuffaceous claystone = very light gray to light gray to light grayish brown; smooth to silty/sandy texture with interbedded fine to medium grained clayey sand; moderately to very hydrophilic; occasionally calcareous; non to slightly organic to rare carbonaceous shale. 7330 Tuffaceous claystone = very light gray to light gray to light brownish gray; smooth to some silty/sandy texture with possible rare thin beds clayey sand; moderately to very hydrophilic; non to slightly organic; slight calcareous matter. 7370 Coal = brownish black to black; firm to moderately firm; moderately to slightly brittle; hackly to subplaty fracture; dull to slightly shiny luster; lignite to subbituminous; massive to some carbonaceous shale partings and thin beds. 7410 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy to somewhat firm; gritty, silty texture; dull luster when dry; occurs as soft runny lumps in sample; common shards, sand and silt embedded in matrix; grades to an argillaceous sand in part; common detrital coal fines and black to brown specks of organic material; thin interbeds of coal and commonly soft, dark brown organic shale. 7490 Coal = black; hard to moderately firm; brittle and crunchy; shiny, vitreous luster; blocky to tabular cuttings habit; common conchoidal and hackly fracture; no visible bleeding gas. 7525 Tuffaceous claystone = very light gray to light gray to light brownish gray; smooth to some silty/sandy texture with possible rare thin beds clayey sand; moderately to very hydrophilic; slightly to non organic; often moderately calcareous including calcite. 7565 Coal"" grayish black to black to brownish black; very firm and slightly brittle to slightly firm and crunchy; slightly shiny to dull luster; subplaty to hackly fracture; massive to occurring as [=I EPOCH 22 ~ '/""". UNOCAL8 A-15RD thin beds and partings in carbonaceous to tuffaceous claystone; lignite to subbituminous; very slight micropyrite specs; slight bleeding gas. 7615 Tuffaceous claystone = medium light gray to light brownish gray; soft to moderately soft and hydrophilic to slightly hydrophilic; smooth to silty/gritty texture locally grading siltstone to fine sandstone with slightly scattered medium to coarse grains; mostly slightly organic; some weakly mottled to thin laminations and partings of carbonaceous matter and coal; often with silty calcareous matter; trace mica 7675 Sand = medium light gray; very fine to medium lower grains and scattered coarse; angular to subangular; moderate to moderately high sphericity; moderately to poorly sorted; some with clay matrix and some frosted to sand clusters with calcareous cement; 80% quartz, and 20% mostly black partially siliceous coal fines, and some red and green including feldspar and siliceous grains; estimate mostly poor to fair porosity and permeability; no oil indicators. 7750 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; rough striated surfaces with conchoidal to hackly fracture; tabular to irregular cuttings habit; thin interbeds of dark brown fissile carbonaceous shale; rare very thin sand laminations on partings; common visible bleeding gas. 7805 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy to somewhat firm; gritty, silty texture; dull luster when dry; occurs as soft runny lumps in sample; common ash shards embedded in matrix; common specks and micro laminations of brown carbonaceous material grading to an organic claystone in part; occasional stringers of silt and very fine grain sand; trace conglomerate, noncalcareous; probably kaolinitic. 7870 Sand = light gray; very fine to fine grain angular to sub rounded; fairly well sorted; moderate sphericity; +95% of sample is loose grains with no cement or matrix; rare clusters cemented with calcareous clay; sand is 90% quartz, 10% chert, silt, and dark lithics; estimate fair in situ porosity; no fluorescence, no visible stain, no cut. 7940 Tuffaceous claystone = very light gray to light brown; moderately soluble in water mushy to somewhat firm; gritty, silty texture; dull luster when dry; occurs as soft runny lumps in sample; common ash shards embedded in matrix; common specks and micro laminations of brown carbonaceous material grading to an organic claystone in part; occasional stringers of silt and very fine grain sand; non calcareous; probably kaolinitic. ~ EPOCH 23 ~ ~ UNOCAL8 A-15RD 8005 Sand = light gray to light brownish gray; very fine to fine grain dominantly very fine grain; angular to sub angular; poor to fairly well sorted; poor sphericity in most of sample; nearly 100% of sample is loose, unconsolidated grains with light calcite cement; common calcite flakes; some soluble clay matrix that is removed during washing; sample is +90% quartz with minor chert and dark igneous and metamorphic fragments; estimate poor to fair in situ porosity; no visible oil stain; no fluorescence; no cut fluorescence; abundant cavings of coal, many of large size. 8085 Sand = light gray to light brownish gray; very fine to fine grain dominantly very fine grain; angular to subangular; poorly to fairly well sorted; poor sphericity in most of sample; nearly 100% of sample is loose, unconsolidated grains; occasional loosely cemented clusters with white calcareous cement; trace clusters showing light clay matrix; common thin chips of calcite possibly a fracture or joint filling; sample is 90% quartz, 10% chert, dark lithics, silt and trace mica; estimate fair in situ porosity; no visible oil stain, no fluorescence, no cut. 8165 Sand=very light gray; very fine to fine grain; angular to sub angular, rare subrounded; moderately well sorted; fair sphericity; over 90% of the sample is loose, disaggregated sand grains; rare weakly cemented clusters with white calcareous cement which also coats some individual grains; trace of light color soluble clay matrix; most of matrix washes away during sample cleaning; sand is 80% quartz, 20% dark rock fragments, feldspar, chert, coal fines and mica; no visible oil stain, fluorescence or cut. 8255 Tuffaceous claystone = light gray to some white to occasionally light brownish gray; mostly slightly to moderately sandy to slightly silty including very fine to some medium and scattered coarse grains; some calcareous in part possibly tuff; moderately hydrophilic; some slightly organic including coal fines; often grading matrix supported sand. 8305 Tuffaceous claystone = very light gray to white to light grayish brown; soft to very soft and moderately to slightly hydrophilic; sandy and slightly silty texture to smooth; occasionally grading matrix supported sandstone; some slightly organic often with carbonaceous partings and coal streaks rare grading carbonaceous shale; rare thin beds of lignite; some calcareous in part. 8360 Sand = very light gray to medium light gray; very fine to medium grains and scattered coarse to very coarse and trace pebble; angular to subangular; moderately low to moderately high sphericity; mostly loose grains to occasionally matrix supported in kaolic clay; estimate moderately to poorly sorted; 80% quartz, and 20% black to gray to red to white to green [~ EPOCH 24 ~ ~ UNOCAL8 A-15RD lithics including partially siliceous coal, some silicates including feldspar, and minor chert and calcareous matter; estimate mostly fair porosity and permeability; no oil indicated. 8495 Coal = black to brownish black; very firm and slightly brittle to slightly firm and brittle; polished to dull luster; some scours dark rusty brown; subblocky to splintery; mostly dense with visible planar to subplanar lamina; lignite to subbituminous; massive to some thin beds and partings in carbonaceous to tuffaceous claystone. 8545 Tuffaceous claystone = medium dark gray to some brownish gray to medium gray; slightly firm; subblocky to amorphous with rounded edges, and often curly shavings with PDC bit markings; smooth to some silty texture; some with thin coal partings; some organic in part obscured by oil based mud contamination; often calcareous in part including calcite. 8600 Tuffaceous claystone = medium light gray to medium dark gray; slightly firm to firm; smooth to some silty/gritty texture; occasionally grading matrix supported sandstone in kaolic/ashy clay; slight loose fine to medium mostly quartz grains; possibly some organic obscured by oil mud contamination; occasionally calcareous to slightly calcareous. 8655 Coal = black to dark grayish brown; very firm and slightly brittle to slightly firm and crunchy; subblocky to subplaty to irregular hackly fracture; lignite to some subbituminous; moderately shiny to earthy luster; massive to thinly interbedded in and grading to carbonaceous shale; trace grading sandstone. 8700 Sand = very light gray to light gray; medium to some very fine and scattered coarse to trace pebble; subangular to angular; moderately to moderately well sorted; possible very slight overall clay matrix; 85% quartz, and 15% black to gray to rare red, white, and green lithics including coal fines, clays, chert and silicates; estimate good to fair porosity and permeability; oil indicators obscured by oil based mud. 8780 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; rough striated surfaces with conchoidal to hackly fracture; tabular to irregular cuttings habit; occasional interbedded with and grading into carbonaceous shale. 8825 Conglomeratic sand = light gray; very fine to very coarse, especially fine to medium, and scattered to locally some pebbles and fragments; subangular to angular; moderately to poorly sorted with overall slight to some moderate kaolic clay matrix; locally very poorly [:I EPOCH 25 ~ ,r-" UNOCALG) A-15RD sorted grading conglomerate and sandy conglomeratic clay; 80% quartz, and 20% black to gray to rare red and white lithics including coal fines, clay, and silicates including feldspar partially altered to clay, partially siliceous lithics and chert, with chert increasing in conglomeratic fraction; estimate fair to very poor porosity and permeability; oil indicators obscured by oil based mud contamination. 8925 Conglomeratic sand = medium light gray; very fine to very coarse, especially fine to medium, to scattered and locally common pebbles and fragments; subangular to angular; poorly to some moderately sorted with slight to moderate clay matrix to locally interbedded conglomerate, tuffaceous and carbonaceous claystone, and kaolic ash; 70% quartz, and 30% clay and coal clasts, chert, partially siliceous lithics, and silicates including feldspar often altered to clay; very poor to fair estimated porosity and permeability, oil indicators obscured by oil based mud contamination. 9005 Conglomeratic sand/sand = medium light gray to light gray; very fine to very coarse, especially medium to coarse lower, and scattered pebbles and fragments; angular to subrounded; moderate sphericity; moderately well to some poorly sorted; slight overall clay matrix to locally interbedded claystone; 85% quartz, and 15% black to gray to rare red and green lithics including partially siliceous coals and clays, chert, and silicates commonly altered to clay; estimate some fair to good porosity and permeability; oil indicators obscured by oil based mud contamination. 9090 Sand = medium light gray to light gray; dominantly very fine to medium grains, occasional coarse to very coarse; well sorted to moderately well sorted; subrounded to subangular, occasional angular bit impacted grains; 80% quartz, and 20% black, gray, red and green opaque lithic fragments; estimate fair to good porosity and permeability; oil indicators masked by oil based mud. 9165 Sand/conglomeratic sand = medium light olive gray to light gray; fine to coarse grained, especially medium, with slightly scattered to locally some pebbles and fragments; subangular to angular; estimate moderately well to some poorly sorted with overall slight clay matrix increasing to moderate at top of sand; rare very poorly sorted grading conglomerate; 85% quartz, and 15% partially siliceous coal and clay clasts and minor partially clay altered silicates and calcareous matter; estimate mostly fair porosity and permeability; oil indicators obscured by oil mud. 9245 Coal = black to grayish black; very firm and slightly brittle to slightly firm and crumbly; hackly to subblocky fracture; subbituminous to some lignite; massive to occasionally thinly bedded in slightly to very organic claystone; rare thinly bedded sandy tuff. 9285 [:I EPOCH 26 -- .----..., UNOCAL8 A-15RD Carbonaceous shale = dark brownish gray to medium gray; slightly firm to firm; moderately hydrophilic expanding to light grayish brown to brownish gray; subplaty often with rounded edges; smooth to sandy/silty texture with interbedded fine to lower medium clayey sand and occasional siltstone; moderately to some slightly organic with occasional thin beds and partings of coal; occasional tuffaceous claystone and tuff; noncalcareous. 9350 Coal = black to brownish black; very firm and slightly brittle to slightly firm and crunchy; occasionally scours dark rusty brown; hackly to subplaty to flaky fracture; mostly lignite to some subbituminous; massive to thinly bedded and partings in organic claystone; some low grade lignite grading carbonaceous shale. 9400 Sand = medium light gray to light olive gray; very fine to coarse lower, especially medium to fine, and rare scattered pebbles and fragments; subangular to angular; moderately to poorly sorted generally fining upward; slight overall clay matrix and rare grading sandy claystone; 75% quartz, and 25% black to gray to brown partially siliceous coal and clay fines, and rare red to trace green lithics including feldspar; estimate fair to some poor porosity and permeability; oil indicators obscured by oil based mud contamination. ,9495 Sand/conglomeratic sand = medium gray to medium light gray; very fine to lower coarse, dominantly fine to medium, occasional coarse to very coarse; moderately to well sorted; subround to subangular, occasional angular bit impacted grains; mostly unconsolidated, rare cuttings of indurated sandstone; mostly clay matrix, rare grading to siltstone and sandy claystone; 70% quartz, 15% chert and 15% lithic fragments; oil indicators masked by oil based mud contamination. 9565 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm; subblocky to amorphous with rounded edges, dull to earthy luster; clayey to some silty texture; occasional thin interbedded layers of black carbonaceous material, some grading into carbonaceous shale. 9610 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; greasy to slightly shiny luster; rough striated surfaces with conchoidal to hackly fracture; tabular to irregular cuttings habit; occasional thin interbeds of carbonaceous shale, some grading to claystone; common visible gas bleeds. 9660 Sand = light gray to medium light gray; dominantly very fine upper to medium, occasional coarse to very coarse temporally increasing towards bottom of sand; moderately well to well sorted; subrounded to subangular, some larger bit impacted grains; probable clay [j EPOCH 27 ~ ~ UNOCAL8 A-15RD matrix; 75% quartz, 15% chert and 10% volcanic, metamorphic and lithic fragments; oil indicators masked by oil based mud contamination. 9720 Coal = black to brownish black; tough to firm, occasionally brittle; subpolished to dull luster; blocky to splintery fracture with common conchoidal; smooth to gritty; occasional grading to carbonaceous shale; some visible gas bleeding. 9765 Conglomeratic sand/sand = medium light gray to light olive gray; fine to coarse especially medium to coarse lower, and scattered very coarse fragments and trace pebbles; angular to subangular; overall moderately to poorly sorted in slight to moderate kaolic clay matrix; occasional interbeds sandy conglomeratic claystone; 75% quartz, and 25% coal and clay clasts, some partially siliceous, trace red and green silicates, and trace chert including pebbles; locally interbedded coal; estimate mostly poor to some fair porosity and permeability; oil indicators obscured by oil based mud contamination. 9850 Conglomeratic sand = medium light gray to olive gray; very fine to very coarse and scattered fragments and pebbles; subangular to angular; moderate sphericity; poorly to moderately sorted in slight to moderate kaolic clay matrix occasionally grading claystone and minor conglomerate; 75% quartz, and 25% black to some gray to opaque to trace red lithics including coal and clay clasts, and rare silicates and chert; some calcareous matter including tuff; estimate mostly poor to some fair porosity and permeability; oil indicators obscured by oil based mud contamination. 9930 Carbonaceous shale = dark grayish brown to brownish gray; firm to slightly firm; smooth to some silty to sandy including fine to medium grains; hydrophilic expanding to light brownish gray to light grayish brown; organic to slightly organic with interbedded kaolic/ashy clays, sands, conglomerates, and calcareous matter possibly tuff and calcite; some grading coal with thin beds and partings of lignite. 9990 Conglomeratic sand/sand = olive gray to light olive gray; medium to very fine and scattered to locally common coarse grains, fragments and pebbles; angular to subangular; moderately to poorly sorted in slight to occasionally moderate clay matrix, calcareous in part; 80% quartz, and 20% black to gray coal and clay fines and clasts, rare red probably feldspar, and rare chert and siliceous lithics; estimate mostly poor to fair and occasionally good porosity and permeability; oil indicators obscured by oil based mud contamination. 10070 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; rough striated surfaces with conchoidal to hackly fracture; tabular to [j EPOCH 28 ----- ~ UNOCAL8 A-15RD irregular cuttings habit; occasional thin interbeds of carbonaceous shale, some grading to claystone; common visible gas bleeds 10120 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm; subblocky to amorphous with rounded edges, dull to earthy luster; clayey to some silty texture; slightly to noncalcareous; occasional thin interbedded layers of black carbonaceous material, some grading into carbonaceous shale. 10170 Carbonaceous shale = dark brownish gray to brownish gray; slightly firm to firm; irregular to blocky; dull to earthy luster; clayey to silty texture, occasional grading to and interbedded with very fine to lower medium sand; laminations of carbonaceous matter and lignite not uncommon; slightly to moderately hydrophilic; slightly calcareous. 1 0225 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; conchoidal to hackly fracture; tabular to irregular cuttings habit; occasional thin interbeds of carbonaceous shale, rare grading to clay; visible gas bleeding. 10270 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm; subblocky to amorphous with rounded edges, dull to earthy luster; clayey to some silty texture; slightly to noncalcareous. 10320,sand = olive gray; medium to fine grains and scattered coarse to trace very coarse; subangular to angular; moderate spheriodal sphericity; moderately well to some poorly sorted in overall slight to some moderate kaolic/slight organic clay matrix; some matrix calcareous in part; occasionally grading tuffaceous to carbonaceous claystone; trace siliceous streaks in claystone; 75% quartz, and 25% black to brownish gray to gray to rare red mostly coal and clay fines and clasts and minor siliceous lithics, feldspar, and chert; estimate fair overall porosity and permeability; oil indicators obscured by oil mud. 10405 Sand = olive gray; very fine to coarse generally fining upward and locally conglomeratic; angular to subrounded; moderately to poorly sorted in overall slight to moderate clay matrix; clay kaolic and often slightly organic; 75% quartz, and 25% black to grayish brown to gray to opaque to rare red grains including coal and clay fines and clasts some slightly siliceous, and minor feldspar; estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 10475 Sandstone/sand = olive gray to light gray; very fine to coarse grained, especially fine to medium lower, with locally scattered very coarse to pebble; angular to subangular; poorly to [~ EPOCH 29 I""""'. "'--"', UNOCAL8 A-15RD moderately sorted in slight to moderate kaolic ashy clay matrix grading devitrified tuff; some matrix slightly organic; 80% quartz, and 20% black to gray to trace red lithics; locally interbedded lignite and rare thin conglomerate; estimate poor to fair porosity and permeability; oil indicators masked by oil mud 10575 Sand = light gray to medium light gray; dominantly very fine upper to medium, occasional coarse to very coarse increasing towards bottom of sand; moderately well to well sorted; subangular to subrounded, some large bit impacted grains; probable clay and ashy matrix; 80% quartz, 20% gray and black lithic fragments, with trace red and green. 10630 Sand/conglomeratic sand = medium gray to medium light gray; very fine to lower coarse, dominantly fine to medium, occasional coarse to very coarse; moderately to well sorted; subrounded to subangular, occasional angular bit impacted grains; mostly unconsolidated, rare cuttings of indurated sandstone; mostly clay matrix. 10700 Coal = black to grayish black; moderately firm to slightly firm and moderately brittle to crumbly; mostly scours dark rusty brown; lignite bedded in conglomeratic claystone with rare pebbles and siliceous clay nodules/clasts. 10735 Sand = light olive gray to medium light gray; medium to very fine grains, especially medium to fine, and slightly scattered to locally common coarse to pebble and fragments; angular to subangular; moderately to poorly sorted with overall slight clay matrix; locally grading claystone and conglomerate; fair to poor estimated porosity and permeability; scattered light brown stain 10730'-50'; even light green yellow fluorescence and cut undifferentiated from oil based mud. 10805 Conglomeratic sand/sand = light olive gray to olive gray; very fine to coarse, especially medium, and scattered to locally common fragments, very coarse, and pebbles; angular to subangular; moderately to poorly sorted with slight to some moderate clay matrix locally grading claystone and conglomerate; 80% quartz, and 20% coal and clay, some partially siliceous lithics and chert, and silicates; estimate poor to fair porosity and permeability; trace possible stain; cut and fluorescence undifferentiated from oil based mud. 10880 Conglomeratic sand = light olive gray to olive gray; very fine to very coarse, especially fine upper to coarse lower, and scattered to locally common fragments and pebbles; poorly to moderately sorted; 80% quartz, and 20% black to gray to light green to rare red coal and clay clasts, minor siliceous lithics and chert, and minor silicates; occasionally grading conglomerate and claystone and rare thin beds of coal; estimate poor to fair porosity and permeability; oil indicators masked by oil based mud. [=I EPOCH 30 /"'"'" .~ UNOCAL8 A-15RD 10955 Sand/conglomeratic sand = medium gray to medium light gray to light olive gray; very fine to coarse, dominantly fine to medium, occasional coarse to very coarse; moderately to poorly sorted; subangular to angular with common bit impacted grains; mostly unconsolidated, rare cuttings of indurated sandstone; mostly clayey to ashy matrix; some grading to silt and sandy clay, rare interbedded with organic matter and coal 70% quartz, 10% chert and 20% gray and black lithic fragments to rare green and red, occasional feldspar; estimate poor to fair porosity and permeability; oil indicators masked by oil based mud contamination. 11045 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm to firm; subblocky to amorphous cuttings with rounded edges; dull to earthy luster; clayey to some silty texture; occasional thin interbedded layers of black carbonaceous material, some grading into carbonaceous shale; non to slightly calcareous. 11095 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; conchoidal to hackly fracture; tabular to irregular cuttings habit; occasional thin interbeds of carbonaceous shale; some visible gas bleeding. 11160 Tuffaceous claystone = light gray to medium gray; moderately soft to some moderately firm; amorphous to subplaty; greasy to earthy luster; hydrophilic; kaolic/ashy grading tuff to some organic grading carbonaceous shale; smooth to gritty texture; often grading matrix supported sandstone and conglomerate with quartz, coal, silicate, clay, and chert clasts; trace red feldspar partially altered to clay. 11220 Sand = olive gray to light olive gray; fine to medium grains and scattered to locally common coarse grains, fragments, and pebbles; subangular to angular; moderately to poorly sorted in slight to some moderate clay matrix locally grading matrix supported sandstone, 11255 Conglomerate, and claystone; some claystone organic with thin beds coal; 75% quartz, and 25% coal and clay fines and clasts, minor siliceous lithics, chert, feldspar and other silicates; estimate poor to some fair porosity and permeability; oil indicators masked by oil based mud contamination. 11335 Tuffaceous claystone = medium gray to light gray, some brownish gray; soft to slightly firm; subblocky to amorphous cuttings with rounded edges; dull to earthy luster; clayey to [:I EPOCH 31 ~. ~ UNOCALfi) A-15RD some silty texture; occasional thin interbedded layers of black carbonaceous material, some grading into carbonaceous shale; non to slightly calcareous. 11390 Coal = black to some brownish black; moderately firm and moderately brittle to slightly firm and crumbly; moderately shiny luster; hackly to subplaty fracture with visible subplanar lamina; massive to thin beds in dusky brown carbonaceous shale; lignite to subbituminous. 11435 Carbonaceous shale = dusky brown to brownish gray; moderately soft to slightly firm; amorphous to subplaty to subfissile; smooth to some sandy/silty texture with occasional thin beds fine to very fine grained sand; very to slightly organic grading claystone; often grading to and thin beds and partings of lignite. 11485 Sand = olive gray to medium dark gray; fine to very coarse, especially fine upper to coarse lower; angular to subangular; poorly to moderately sorted in slight to moderate clay matrix, variably organic grading claystone and coal, and some calcareous; 70% quartz, and 30% coal, clay, calcite, and minor feldspar; estimate poor to some fair porosity and permeability; oil masked by oil base mud. 11540 Sand = olive gray to light olive gray; very fine to coarse lower, especially medium to fine upper, and locally scattered coarse and fragments; subangular to angular; moderately well sorted in very slight clay matrix; 85% quartz and 15% mostly coal and clay lithics; mostly fair to good porosity and permeability; poorly sorted with interbedded clay and coal lower; oil indicators masked by oil based mud contamination. 11600 Sand = light olive gray to olive gray; fine to very coarse grains, especially medium to fine upper, subangular to angular; moderate sphericity; moderately well to moderately sorted in very slight overall clay matrix; 75% quartz, and 25% gray to black to trace opaque and red lithics including mostly clay and coal fines, and minor feldspar and calcareous matter; rare matrix supported streaks; estimate mostly fair porosity and permeability; oil indicators masked by oil based mud contamination. 11690 Coal = black to dark brownish black; hard to slightly firm; moderately brittle to crunchy; dull to slightly shiny luster; conchoidal to hackly fracture, some parting along subplanar laminations; often grading to and interbedded with carbonaceous shale; lignite to subbituminous. 11735 [~ EPOCH 32 ~ r--.., UNOCAL8 A-15RD Sand = light olive gray to medium gray overall, dominantly clear to translucent white grains, some gray to black rare red and green; very fine to coarse, mostly fine to medium, occasional very coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; unconsolidated; grading lower to poorly sorted conglomeratic sand and conglomerate; overall 75% quartz, and 25% lithic and coarse metalithic fragments, and slight calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 11830 Coal = black to grayish black; scours dark gray to rusty brown; firm and moderately brittle to slightly firm and crumbly; hackly to subblocky and rare conchoidal fracture; subbituminous to lignite; massive to interbedded in mostly carbonaceous shale. 11870 Carbonaceous shale = dusky brown to brownish black to medium dark gray; firm to moderately soft; moderately hydrophilic; amorphous to subplaty with rounded edges; possibly reworked in part in conglomerate; smooth to slight silty/fine sandy texture; some grading slightly organic claystone to siltstone; some coal partings and interbedded coal; rare interbedded mostly fine sand; occasionally calcareous. 11930 Coal = black to brownish black; firm and slightly brittle to slightly firm and crumbly; hackly to subplaty fracture; scours brownish black to rusty brown; slightly shiny luster; subbituminous to lignite; massive to interbedded in mostly carbonaceous shale. 11990 Sand = light olive gray to medium gray overall, dominantly clear to translucent white grains, some gray to black rare red and green; very fine to coarse, mostly fine to medium, occasional very coarse and bit impacted fragments; subangular to angular; dominantly unconsolidated, occasional friable, consolidated cuttings; mostly moderately sorted, grading to poorly sorted conglomeratic sand; 70% quartz, 30% assorted lithic and metalithic fragments and slight calcareous; estimate fair porosity and permeability; oil indicators obscured by oil based mud contamination. 12075 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm to soft; subblocky to amorphous cuttings with rounded edges; dull to earthy luster; smooth to gritty texture; occasional grading to silt and very fine sand, non to slightly calcareous. 12125 Claystone = brownish black to medium dark gray to rusty brown to occasionally very light gray; firm to soft; subplaty with rounded edges and some apparent fissility, to amorphous; hydrophilic; smooth texture; earthy to greasy luster; mostly very to slightly organic some with coal partings to interbedded with coal; kaolic/ashy in part grading tuff and rare with [j EPOCH 33 ~ /----., UNOCAL8 A-15RD green hue as possibly chloritic; possible thin sand stringers especially associated kaolic clays. 12190 Coal = black to brownish black; scours dusky brown; firm and moderately brittle to slightly firm and crunchy; slightly shiny luster; hackly to subblocky to platy fracture; subbituminous to lignite and massive to interbedded with carbonaceous shale. 12230 Claystone = brownish gray to grayish black to medium dark gray to light gray; hydrophilic; firm to moderately soft; smooth to silty texture with thin interbeds of mostly fine to very fine sand; variably organic with partings to interbedded coal; occasional kaolic/ashy with greasy luster. 12295 Tuffaceous claystone = medium dark gray to medium gray, some brownish gray; slightly firm to soft; subblocky to amorphous cuttings with rounded edges; dull to earthy luster; smooth to gritty texture; common grading to carbonaceous shale and interbedding with organic material and coal, rare grading to silt and very fine sand; non to slightly calcareous. 12355 Sand = olive gray to medium gray; medium to fine grains and slightly scattered fine to coarse fragments; subangular; moderately well sorted in probable slight overall clay matrix unconsolidated in sample; grading finer sand and slightly organic kaolic clay supported sandstone interbedded with slightly to moderately organic clayey siltstone and claystone with possible rare coal streaks and partings; 80% quartz, and 20% mostly coal and clay lithics; estimate some fair to good porosity and permeability; oil indicators masked by oil mud contamination. BEGIN A 15RDST1 10430 Sand = medium light gray to medium gray, dominantly clear to translucent white grains, occasional gray and black, rare light green, light red to light orange; very fine to medium size grains, mostly fine to lower medium; moderately well to well sorted; subangular to subrounded; moderate sphericity; unconsolidated; 70% quartz, 20% volcanic, lithic, and metalithic, 10% chert, minor devitrified ash; oil indicators masked by oil based mud contamination. 1 0495 Tuffaceous claystone = medium gray to light gray. some brownish gray; slightly firm to firm, occasional soft; subblocky to amorphous cuttings, some with rounded edges, rare bit metamorphism; dull to earthy luster; smooth to gritty texture, occasionally grading to ~ EPOCH 34 ,-... ~ UNOCALfI> A-15RD silty, rare to very fine sand; occasional thin interbedded layers of carbonaceous materia/; non to slightly calcareous. 10570 Sand/conglomeratic sand = olive gray to light olive gray; fine to very coarse, especially medium, and scattered to locally common fragments and pebbles; subangular to angular; moderately sorted in slight overall kaolic clay matrix; some streaks clay supported sand and claystone; 80% quartz, and 20% gray to black to red to opaque to trace green including clay to coal fines and clasts, silicates primarily feldspar, and minor chert; estimate some fair to good porosity and permeability; oil indicators masked by oil mud contamination. 10645 Claystone = very light gray to brownish gray to dusky brown; moderately soft to moderately firm; moderately hydrophilic; mostly slightly to very organic grading carbonaceous shale with interbedded coal; some kaolic and tuffaceous; some sandy especially kaolic; interbedded conglomeratic sand and conglomerate; noncalcareous. 10695 Coal = black to brownish black; firm and moderately brittle to slightly firm and crumbly; shiny to earthy luster; hackly to angular to flaky fracture; lignite to subbituminous; interbedded in carbonaceous to conglomeratic claystone. 10730 Sand = light olive gray to olive gray; very fine to coarse lower grains, especially medium, and slightly scattered very coarse to pebble; subangular; moderately well to poorly sorted often grading kaolic clay and matrix supported sandstone; trace conglomerate; 80% quartz, and 20% black to gray to opaque to rare red including coal and clay fines, and minor silicates including feldspar; estimate mostly fair to good porosity and permeability; oil indicators masked by oil based mud. 10805 Coal = black to dark brownish black; firm to slightly firm, often brittle to crumbly; hackly to flaky fracture; occasional conchoidal; vitreous to resinous luster; some interbedded with and grading to carbonaceous shale, occasional interbedded with layers of very fine to fine grained sand. 10850 Sand = medium gray to light gray to light olive gray; very fine to lower coarse, dominantly fine to medium, occasional broken pebbles and fragments; moderately to moderately well sorted, some fair to poorly sorted towards bottom of the section; subangular to angular; slight clay matrix, some clay/ashy matrix and minor matrix supported; 80% quartz, 20% black to gray lithic and meta lithic, rare red and green; oil indicators masked by oil based mud contamination. ~ EPOCH 35 /"" ~ UNOCALe A-15RD 10925 Conglomeratic sand = olive gray to light olive gray; fine to coarse, especially fine upper to coarse lower, and common to scattered very coarse, fragments, and pebbles; moderately to poorly sorted in slight to moderate clay matrix with streaks claystone and matrix supported sand; 75% quartz, and 25% gray to black to opaque to red and green lithics including coal and clay clasts, partially siliceous lithics, feldspar, and minor chert; estimate mostly fair porosity and permeability; oil indicator masked by oil based mud contamination. 11035 Tuffaceous claystone = medium gray to light gray, some brownish gray; slightly firm to firm, occasional soft; subblocky to amorphous cuttings, some with rounded edges, rare bit metamorphism; dull to earthy luster; smooth to gritty texture, occasionally grading to silty, rare to very fine sand; occasional thin interbedded layers of carbonaceous material; non to slightly calcareous. 11095 Coal = black to brownish black; moderately firm and moderately brittle to slightly firm and crumbly; polished to earthy luster; hackly to flaky fracture; lignite to some subbituminous; massive to grading carbonaceous shale and minor conglomeratic claystone to sandstone. 11140 Sandstone/sand = olive gray to light gray; fine to coarse lower, especially medium, and locally scattered to common coarse grains, fragments, and pebbles; angular to subrounded; moderately to poorly sorted in ashy/kaolic matrix grading matrix supported sandstone to claystone; 70% quartz and 30% black to some gray to rare red fines and clasts, including coal and clay and rare chert and silicates; locally grading conglomerate associated with thin coal zones, siliceous clasts, and red feldspar partially altered to clay; estimate mostly poor to fair porosity and permeability; oil indicators masked by oil based mud. 11245 Coal = black to dark brownish black; firm to slightly firm, often brittle to crumbly; hackly to flaky fracture; occasional conchoidal; vitreous to resinous luster; some interbedded with and grading to carbonaceous shale, occasional interbedded with layers of very fine to fine grained sand. 11290 Carbonaceous shale = dusky brown to brownish black to brownish gray; firm to moderately soft; moderately to slightly hydrophilic; subblocky to subplaty, some with rounded edges; smooth to silty texture; commonly grading to organic claystone and siltstone; occasional thin beds of lignite; rare interbedded layers of very fine to fine grained sand; non to slightly calcareous. ~ EPOCH 36 ,,-... . ~ UNOCALe A-15RD 11350 Tuffaceous claystone = medium gray to light gray, some brownish gray; slightly firm to firm, occasional soft; subblocky to amorphous cuttings, some with rounded edges; dull to earthy luster; moderately to slightly hydrophilic; dominantly smooth to gritty texture, occasional grading to very fine sand; often grading to organic claystone and interbedded with carbonaceous material and lignite; non to slightly calcareous. 11420 Carbonaceous shale = brownish gray to dark grayish brown; mostly slightly firm to moderately soft and subplaty with incipient fissility; occasionally very firm with rounded edges possibly reworked as conglomerate and slightly siliceous; overall moderately organic with micro thin partings and remnant flakes of carbonaceous matter; grading slightly organic claystone; massive to interbedded with sandy claystone, clayey sandstone, and conglomerate. 11485 Coal = black to some brownish black; scours dark brownish gray to dusky brown; moderately firm and moderately brittle to slightly firm and crumbly; hackly to subplaty fracture; massive to thinly bedded in carbonaceous shale; moderately shiny luster; lignite to subbituminous. 11530 Conglomeratic sand/sand = olive gray; coarse lower to fine, especially medium, and locally scattered to common coarse to trace pebble; subangular to subrounded; moderately to poorly sorted in ashy/kaolic matrix grading grain supported sandstone and claystone; 70% quartz, and 30% black to gray to red to white grains including coal, clay, feldspar, other silicates, and calcite; estimate mostly poor to fair porosity and permeability; oil indicators obscured by oil based mud contamination. 11620 Sand/conglomeratic sand = light olive gray to olive gray to medium gray; very fine to lower coarse, dominantly upper very fine to medium grained, some bit impacted coarse, pebbles and fragments; subangular to angular; moderately to poorly sorted; ashy/clay matrix occasionally grading to grain supported; 70% quartz, 30% various lithic, metalithic fragments, chert, devitrified ash and feldspar; oil indicators obscured by oil based mud contamination. 11685 Coal = black to dark brownish black; firm to slightly firm, often brittle to crumbly; hackly to flaky fracture; occasional conchoidal; vitreous to resinous luster; some interbedded with and grading to carbonaceous shale, lignite to subbituminous. 11745 [:I EPOCH 37 ,,--..., ~. UNOCALt) A-15RD Sand/conglomeratic sand = olive gray; fine to very coarse, especially medium; subangular; moderately sorted in slightly organic kaolic matrix; 75% quartz, and 25% gray to black to some white, red, and green grains including coal, clay, and minor feldspar; locally grading conglomeratic sand and conglomerate with reworked lithic clasts, trace siliceous; some interbedded claystone and coal; estimate poor to some fair porosity and permeability; oil indicators masked by oil based mud. 11810 Conglomeratic sand = olive gray to light olive gray; fine to very coarse, especially medium to fine; slight to locally common pebbles; subangular to angular; poorly to moderately sorted in slightly organic kaolic matrix with streaks to thin beds claystone and matrix supported sand; 70% quartz, and 30% lithic fines and clasts; grading conglomerate with increased lithic clasts and minor chert; poor to some fair porosity; oil indicators masked by oil based mud. 11880 Carbonaceous shale = dark brownish gray to medium dark gray; firm to some soft; overall moderately organic grading kaolic claystone; smooth to some silty texture; some sandy especially kaolic; massive to interbedded with sandstone and minor conglomerate. 11925 Coal = black to dark brownish black; firm to slightly firm, often brittle to crumbly; hackly to flaky fracture; occasional conchoidal; shiny to resinous luster; some interbedded with and grading to carbonaceous shale, occasional interbedded with layers of very fine to fine grained sand; subbituminous to lignite. 11975 Carbonaceous shale = dusky brown to brownish black to brownish gray; firm to moderately soft; moderately to slightly hydrophilic; subblocky to subplaty, some with rounded edges; smooth to silty texture; commonly grading to organic claystone and siltstone; occasional thin beds of lignite; rare interbedded layers of very fine to fine grained sand; non to slightly calcareous. 12035 Sand = medium gray to light gray to light olive gray; very fine to lower coarse, dominantly fine to medium, occasional broken pebbles and fragments; moderately to moderately well sorted, some fair to poorly sorted; subangular to angular; slight clay matrix, some clay/ashy matrix and minor matrix supported; 80% quartz, 20% black to gray lithic and meta lithic, rare red and green; estimate poor to fair porosity and permeability; oil indicators obscured by oil based mud. 12120 Carbonaceous shale = dark gray to dark brownish gray to medium gray; firm to slightly firm; moderately hydrophilic overall; moderately organic with intermittent coal streaks, to slightly organic grading kaolic claystone; smooth to silty to fine sandy texture; common [~ EPOCH 38 ~ ~ UNOCAL8 A-15RD thin beds and laminations of siltstone to sandstone, very fine to medium grained; rare calcareous matter. 12175 Coal = black to grayish black; brittle to slightly brittle; hackly to flaky fracture; slightly shiny to shiny; subbituminous to lignite; massive; bedded in sandy kaolic to organic claystone. 12215 Tuffaceous claystone = medium gray to light gray, some brownish gray; slightly firm to firm, occasional soft; subblocky to amorphous cuttings, some with rounded edges; dull to earthy luster; moderately to slightly hydrophilic; dominantly smooth to gritty texture; often grading to organic claystone and interbedded with carbonaceous shale and lignite; non to slightly calcareous. 12275 Coal = black to dark brownish black; firm to slightly firm, often brittle to crumbly; hackly to flaky fracture; occasional conchoidal; shiny to resinous luster; some interbedded with and grading to carbonaceous shale, occasional interbedded with layers of very fine to fine grained sand; subbituminous to lignite. 12330 Carbonaceous shale = dark gray to medium dark gray to brownish gray; moderately soft to slightly firm; subplaty with incipient fissility to amorphous; smooth to some silty to trace sandy texture; moderately organic overall with intermittent coal streaks including trace encased in calcite, to often slightly organic; possible occasional thin beds in massive coal. 12415 Sand = olive gray to light olive gray; fine upper to coarse lower grains; subangular to subrounded and slight angular bit impacted fragments; slight very coarse lithic clast; moderately to moderately well sorted; overall 60% quartz and 40% mostly clay and some coallithics, slight calcareous matter, rare feldspar and other silicates, and rare hematite to limonite stained firm flaky matter; estimate mostly fair to good porosity; oil masked by oil mud. 12480 Sand = light olive gray to some olive gray; fine to coarse grains, especially medium to coarse lower; subangular to angular including slight to locally some bit impacted fragments, and occasional very coarse lithic clasts; estimate moderately well to poorly sorted decreasing with greater angularity and increase larger clasts; 70% quartz, and 30% clay, coal, feldspar and other silicates, partially siliceous lithics, and trace chert; some slight clay infilling with trace siliceous streaks; estimate mostly fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 12570 [j EPOCH 39 ~ ~ UNOCAL8 A-15RD Sand = light gray to medium gray to light olive gray; very fine to medium grained, dominantly fine to medium, occasional lower coarse and bit impacted fragments; angular to subangular; moderately well to moderately sorted; unconsolidated with probable clay matrix; 70% quartz, 30% gray, black, and brownish lithic fragments with rare red and green; estimate mostly fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 12660 Sand = olive gray to dark gray; fine to coarse lower, especially medium to fine upper; angular to subrounded including slight mostly coarse bit impacted fragments; moderately sorted; 60% quartz, and 40% gray to black to brown to rare red and green, estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 12720 Sand = olive gray to medium gray; very fine to lower coarse, dominantly fine to medium, occasional bit impacted coarse and fragments; subangular to subrounded; moderately to moderately well sorted; 75% quartz, 25% mostly gray, black, and brown lithic fragments, rare green and red; estimate fair to poor porosity and permeability; oil indicators obscured by oil based mud contamination. 12775 Sand = olive gray to dark gray; very fine to lower coarse, mostly upper fine to medium, occasional bit impacted coarse lithic fragments; subangular to angular; moderately to some moderately well sorted; 70% quartz, and 30% clay, coal, feldspar and other silicates, partially siliceous lithics, and trace chert; estimate mostly poor to fair porosity and permeability; oil indicators masked by oil mud contamination. 12840 Sandstone\sand = dusky brown to dark gray; fine to rare coarse lower, especially upper fine to medium, trace bit impacted coarse; subangular to some angular; moderately to poorly sorted in clay matrix grading matrix supported sandstone with streaks and clasts of clay; matrix overall kaolic and slightly organic; 60% quartz, and 40% mostly soft to occasional hard lithics including clay, coal, minor silicates including feldspar, and trace chert; estimate poor to some fair porosity and permeability; oil indicators masked by oil based mud contamination. 12920 Sandstone = dark gray to dusky brown; medium to very fine grains; subangular to angular; poorly to moderately sorted in slightly organic kaolic clay matrix; some silty texture; grading claystone with streaks and weathered clasts of organic clay; 60% quartz, and 40% mostly soft lithics including clay, coal fines, and weathered silicates; estimate mostly poor porosity and permeability due to clay infilling; oil indicators masked by oil based mud contamination. 12985 [~ EPOCH 40 ,~ ~ UNOCAL8 A-15RD Sandstone = dark gray to dusky brown; very fine to medium grains, especially fine to medium lower; subangular; poorly to moderately sorted in slightly organic kaolic clay matrix and often matrix supported; streaks and thin beds grading to claystone, some with silty texture; grains mostly quartz, and some clay, coal, weathered lithics, and feldspar and other silicates; estimate mostly poor porosity and permeability; oil indicators masked by oil based mud contamination. 13070 Coal = black to brownish black; firm to hard, occasionally brittle to crunchy; slightly shiny to dull luster; subblocky to hackly fracture, occasional subplaty; grading to carbonaceous shale and occasional interbedded with very fine sand; subbituminous to lignite. 13110 Sand = medium light gray to medium gray to some olive gray; dominantly fine to medium grains, occasional very fine and lower coarse; subrounded to subangular; moderately well to moderately sorted; 65% clear to translucent white quartz, 35% gray, black, and brown lithic fragments including chert, feldspar, claystone, coal and various meta lithic grains; estimate fair to good porosity and permeability; oil indicators masked by oil based mud contamination. 13195 Sandstone/sand = dusky yellow brown to some olive gray; very fine to medium grains, some mostly fine and some mostly medium; angular to subrounded; moderately well to some poorly sorted; mostly grain supported with slightly organic clay matrix to some matrix supported including streaks and clasts of claystone; 60-80% quartz, and 20-40% clay, coal, rare red and green clasts including feldspar, and trace hematite stained flakes; estimate poor to some fair porosity and permeability; oil indicators masked by oil based mud contamination. 13270 Claystone = brownish gray to very dark gray; soft to slightly firm; moderately hydrophilic; subblocky to subplaty to flaky, amorphous to slight incipient fissility; slightly to some moderately organic grading to carbonaceous shale with streaks to possible thin beds coal; slight to very silty/gritty texture grading sandstone, with very fine to medium and scattered coarse grains, and siltstone; slight calcareous matter. 13330 Coal = black to brownish black; slightly firm and brittle to crumbly; hackly to flaky to subplaty fracture; moderately to slightly shiny luster; lignite to subbituminous; massive to grading carbonaceous shale and possible interbedded with sandy claystone. 13425 Coal = black to brownish black; slightly firm to firm and slightly brittle to crumbly; hackly fracture; moderately to slightly shiny luster; subbituminous to lignite; massive to probable [~ EPOCH 41 .~ ~ UNOCAL8 A-15RD occasionally grading carbonaceous shale to sandy claystone to possible clayey sandstone. 13490 Carbonaceous shale = dusky brown to brownish black to dark gray; amorphous to subplaty with slight incipient fissility; occasional laminar flakes; grading to lignite and interlaminated to interbedded with coal; smooth to slightly silty texture; some grading slightly organic sandy claystone and clayey sandstone with fine to medium grains; trace calcareous including calcite. 13560 Tuffaceous siltstone = light brownish gray to light gray; soft to slightly firm; kaolic and overall slightly organic; dull to earthy luster; silty and sandy including very fine to medium grains grading sandstone. BEGIN A15RDST1L 1 12705 Sand = olive gray; fine to medium and scattered coarse grains, very slight coarse bit impacted fragments; subangular; moderately to moderately well sorted in slight overall clay matrix; occasional streaks and lenses grading claystone; 75% quartz, and 25% mostly gray to some black and brown clay and coallithics, red and green grains including feldspar, and trace chert; estimate mostly fair porosity and permeability; oil indicators masked by oil based mud contamination. 12795 Sand = medium gray to light gray, occasional olive gray secondary hue; fine to medium and scattered lower coarse grains, rare bit impacted fragments; moderately to moderately well sorted; dominantly unconsolidated, occasional friable consolidated cuttings with slight clay matrix to occasional grain supported; 70% translucent white to clear quartz, 30% mostly gray to black and brown clay and coallithics, rare red and green grains; estimate mostly fair porosity and permeability; oil indicators obscured by oil based mud contamination. 12875 Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 70% quartz, 30% mostly gray, black, and brownish black lithic fragments including chert, claystone, coal, and scattered feldspar, occasional red and green to bluish green; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 12950 Sand = olive gray to light olive gray; mostly upper fine to medium, some upper medium lower coarse and very fine grains, scattered bit impacted fragments; subangular to angular; [=I EPOCH 42 ,~ ~ UNOCAL8 A-15RD moderately to some slight poorly sorted; probable clay matrix to some grain supported; 70% quartz, 30% gray, black, and brownish black lithic fragments including varying amounts of clay, coal, chert, feldspar and assorted silicates; estimate slightly fair to fair porosity and permeability; oil indicators masked by oil based mud contamination. 13050 Conglomeratic sand/sand = olive gray to light olive gray; fine to coarse grains, common very coarse to coarse bit impacted fragments and pebble fragments; moderately sorted with slight clay matrix to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray to some black and brown clay and coallithics, red and green grains including feldspar and trace chert; estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 13120 Conglomeratic sand/sand = light gray to light olive gray; fine to coarse grains, common very coarse to coarse bit impacted fragments and pebble fragments; moderately sorted with slight clay matrix to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray to some black and brown clay and coallithics, red and green grains including feldspar and trace chert; estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 13190 Conglomeratic sand/sand = medium gray to light olive gray; fine to coarse grains, common very coarse to coarse bit impacted fragments and pebble fragments; moderately sorted with sli clay matrix; to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray to some black and brown clay and coallithics, red and green grains including some feldspar and trace chert; estimate poor to fair porosity and permeability; oil indicators masked by oil based mud contamination. 13260 Sand = medium gray to light gray, occasional olive gray secondary hue; fine to medium and scattered lower coarse grains, rare bit impacted fragments; moderately to moderately well sorted; dominantly unconsolidated, occasional friable consolidated cuttings with slight clay matrix to occasional grain supported; 70% translucent white to clear quartz, 30% mostly gray to black and brown clay lithics; fair permeability and porosity; oil indicators masked by oil based mud contamination. 13300 Tuffaceous claystone = brownish gray to very dark gray; firm to slightly firm, occasionally soft; moderately to fairly hydrophilic; subblocky to subplaty, some flaky; slightly to moderately organic grading to carbonaceous shale, common streaks of coal; slight to very gritty texture grading to very fine to fine grained sand; slight calcareous matter. 13400 [=I EPOCH 43 ~ ~ UNOCAL8 A-15RD Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 70% quartz, 30% mostly gray, black, and scattered feldspar, occasional red to green to bluish green; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination 13465 Conglomeratic sand/sand = medium gray to light olive gray; fine to coarse grains, common very coarse to coarse bit impacted fragments and pebble fragments; moderately sorted with slight clay matrix; to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray to some black and brown clay and coallithics, red and green grains including some feldspar and trace chert; estimate poor to fair porosity and permeability; oil indicators masked by oil based mud. 13530 Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 70% quartz, 30% mostly gray, black, and brownish black lithic fragments including chert, claystone, coal, and scattered feldspar, occasional red and green to bluish green; estimate fair to moderately fair porosity and permeability; oil indicators masked by oil based mud contamination. 13605 Sand = medium light gray to medium gray, with occasional slight olive gray hue; mostly fine to lower coarse grained, some very fine, coarse and bit impacted subangular to angular; moderately to moderately well sorted; dominantly unconsolidated with scattered slightly friable consolidated cuttings; probable clay matrix with occasional grading to grain supported; 60-80% translucent white to clear quartz; 20-40% gray, black and brown lithic fragments, including claystone, coal, and chert, scattered greenstone and rare red to pink grains; trace hematite stained flakes; estimate mostly fair to some moderate porosity and fair permeability; oil indicators obscured by oil based mud contamination. BEGIN A15RDST1L 1A 13500 Sand = medium light gray to medium gray, with occasional slight olive gray secondary hue; mostly upper fine to lower coarse, some very fine, coarse and bit impacted fragments; subangular to angular; moderately sorted; dominantly unconsolidated with scattered slightly friable consolidated cuttings; 60-80% quartz, 20-40% gray, black and brown including chert, claystone and coal, rare red and green; estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 13575 Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 70% quartz, 30% mostly gray, black, ~ EPOCH 44 /"'"' . ~ UNOCAL8 A-15RD and scattered feldspar, occasional red to green to bluish green; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 13655 Sand = light gray to medium gray, with occasional slight olive gray secondary hue; mostly upper fine to lower coarse, some very fine, coarse and bit impacted fragments; sub-angular to angular; moderately sorted; dominantly unconsolidated with scattered slightly friable consolidated cuttings; 60-80% quartz, 20-40% gray, black and brown to rare green and red; estimate fair porosity and permeability; oil indicators masked by oil based mud contaminates 13735 Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 60% quartz, 40% mostly gray, black, and scattered feldspar, occasional red to green; estimate fair porosity; oil indicators masked by oil based mud contamination. 13790 Conglomeratic sand/sand = medium gray to light olive gray; fine to coarse grains, some very coarse to coarse bit impacted fragments; moderately sorted with slight clay matrix to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray to black and brown clay and coallithics, estimate poor to fair porosity; oil indicators masked by oil based mud contamination. 13845 Sand = medium gray to olive gray; very fine to medium grains, dominantly fine to medium, occasional lower coarse and bit impacted fragments; subangular to angular; moderately to moderately well sorted; mostly unconsolidated; 70% quartz, 30% mostly gray, black, and scattered feldspar, occasional red and green to bluish green; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 13910 Conglomeratic sand/sand = light gray to light olive gray; fine to coarse grains, common very coarse to coarse bit impacted fragments and pebble fragments; moderately sorted with slight clay matrix to poorly sorted grading conglomeratic sand; 70% quartz, 30% mostly gray some red and green grains including feldspar and trace chert; estimate fair to poor porosity and permeability; oil indicators masked by oil based mud contamination. 13975 Sand = light gray to medium gray, with occasional slight olive gray secondary hue; mostly upper fine to lower coarse, some very fine, coarse and bit impacted fragments; sub-angular to angular; moderately sorted; dominantly unconsolidated with scattered slightly friable consolidated cuttings; 60% quartz, 40% mostly gray, black, and scattered feldspar, [:I EPOCH 45 ~. ,/""'\ UNOCAL8 A-15RD occasional red and green to bluish green; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. . 14045 Tuffaceous claystone = brownish gray, light to medium gray; firm to slightly firm, occasional soft; fair to moderate hydrophilic; platy to blocky, some flaky; slightly to moderate organic grading to carbonaceous shale, gritty texture grading to a fine grain sand. 14080 Conglomeratic sand/sand = light gray to medium light gray; fine to coarse grains, occasionally very coarse to coarse bit impacted fragments; moderate to poor sorted with clay/ash matrix to poor sorted grading conglomeratic sand; 80% quartz, 20% lithics with traces of feldspar, chert; slightly calcareous; estimate fair to good porosity and permeability; oil indicators masked by oil based mud contamination. 14115 Coal =black to brownish black; tough to brittle; planar to blocky occasionally splintery fracture; flaky cuttings habit; greasy to resinous, occasionally dull luster; smooth to mate texture; slightly visible gas bleeding. 14130 Conglomeratic sand/sand = light gray to medium gray, fine to coarse grains, common very coarse to coarse bit impacted fragments; moderate to poorly sorted with clay/ash matrix to poor sorted grading to conglomeratic sand; 80% quartz, 20% lithics with traces of feldspar, chert; slightly calcareous; estimate fair to good porosity and permeability; oil indicators masked by oil based mud contamination. 14195 Sand = light gray to medium gray, some olive gray; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderately to well sorted; predominantly unconsolidated; 70% quartz, 30% gray, black, red and green grains, including feldspar; slightly to moderately calcareous; fair porosity and permeability; oil indicators masked by oil based mud contamination. 14240 Conglomeratic sand/sand = light gray to medium light gray; fine to coarse grains, occasionally very coarse to coarse bit impacted fragments; moderate to poorly sorted with clay/ash matrix to poorly sorted grading to conglomeratic sand; 80% quartz, 20% lithics with feldspar, chert; light calcareous; estimate fair to good porosity and permeability; oil indicators masked by oil based mud contamination. 14295 Sand = light gray, white, clear, olive gray; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderately to well sorted; predominantly [=I EPOCH 46 r"", ~ UNOCAL8 A-15RD unconsolidated; 70% quartz, 30% gray, black, red and green grains, including feldspar; slightly to moderately calcareous; fair porosity and permeability; oil indicators masked by oil based mud contamination. 14375 Conglomeratic sand/sand = medium gray to light brown gray; medium to coarse grains, occasionally coarse to pebble sized grains; subrounded to subangular, occasionally angular; moderate to low sphericity; 80% quartz, 20% lithics, with red, green, brown grains, including feldspar, chert; moderately calcareous; estimate low porosity and permeability; oil indicators masked by oil based mud contamination. 14415 Sand = light gray to light brown gray; fine to coarse grains, some coarse and bit impacted fragments; subangular to angular; moderate to well sorted; predominantly unconsolidated; 70% quartz, 30% gray, black, red and green grains, including feldspar; moderately calcareous; estimate fair to good porosity and permeability; oil indicators masked by oil based mud contamination. 14465 Tuffaceous claystone = light to medium gray, brownish gray; soft to slightly firm; moderately hydrophilic; blocky to platy, some flaky; moderately organic grading to carbonaceous shell; gritty texture grading to fine grain sand; slightly calcareous. 14495 Sand = light gray, gray, white, clear, some olive gray; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderately to well sorted; predominantly unconsolidated; 70% quartz, 30% gray, black, red and green grains, including feldspar; moderately calcareous; fair porosity and permeability; oil indicators masked by oil based mud contamination. 14550 Conglomeratic sand/sand = medium gray to light brown gray; medium to coarse grains, occasionally coarse to pebble sized grains; subrounded to subangular, occasionally angular; moderate to low sphericity; 80% quartz, 20% lithics, with red, green, brown grains, including feldspar, chert; moderately calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 14590 Sand = light gray to light brown to tan, white, opaque; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderately to well sorted; predominantly unconsolidated; 70% quartz, 30% gray, black, red and green grains, including feldspar; moderately calcareous; fair porosity and permeability; oil indicators masked by oil based mud contamination. 14630 [:I EPOCH 47 /""'. /'""- UNOCAL8 A-15RD Conglomeratic sand/sand = light gray to yellowish gray; fine to medium grains, occasional coarse sized grains; subrounded to subangular, occasionally angular; moderately to low sphericity; 70% quartz, 30% lithics, with red, light and dark green, brown grains, including feldspar, chert; moderately calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 14670 Sand = medium light gray to light olive gray; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderately to well sorted; predominantly unconsolidated; 70% quartz, 30% gray, red, brown, green grains, including feldspar, chert; moderately calcareous; estimate fair porosity and & permeability; oil indicators masked by oil based mud contamination. 14720 Sand = medium light gray to greenish gray; very fine to fine, some medium grains; subangular to subrounded; moderately to subangular to angular; moderately to poor sorted; predominantly unconsolidated; 60% quartz, 40% lithics with clear, light and dark brown, red, green grains, including feldspar, chert; moderately calcareous; estimate low to moderate porosity and permeability; oil indicators masked by oil based mud contamination. 14765 Tuffaceous claystone = light to medium gray, brownish gray; soft to slightly firm; moderate hydrophilic; blocky to platy, some flaky; moderate organic grading to carbonaceous shale; gritty texture grading to fine grain sand; slightly calcareous. 14795 Sand = light gray, gray, some creamy, tan, gray, clear, fine to medium grains, to coarse bit impacted fragments; subangular to angular; moderate to well sorted; predominantly unconsolidated; 70% quartz, 30% lithics with gray, black, red and green grains, including feldspar; moderate calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 14850 Conglomeratic sand/sand = light gray to yellowish gray; fine to medium grains, occasional coarse sized grains; subrounded to subangular, occasional angular; moderate to low sphericity; 70% quartz, 30% lithics, with red, light and dark green, brown grains, including feldspar, chert; moderate calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 14890 Sand = light gray, gray, white, clear, some olive gray; fine to medium grains, some coarse and bit impacted fragments; subangular to angular; moderate to well sorted; predominantly [~ EPOCH 48 r-', ~ UNOCAL8 A-15RD unconsolidated; 80% quartz, 20% lithics, with gray, black, red and green grains, including feldspar; moderately calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 14930 Sand = light gray, gray, creamy, tan, gray, clear, fine to medium grains to coarse and bit impacted fragments; subangular to angular; moderate to well sorted; predominantly unconsolidated; 70% quartz, 30% lithics, with gray, black, red and green grains, including feldspar; moderately calcareous; fair porosity and permeability; oil indicators masked by oil based mud contamination. 14985 Conglomeratic sand/sand = light gray to light olive gray; fine to coarse grains, occasionally very coarse; subrounded to subangular, occasionally angular; moderate to low sphericity; 70% quartz, 30% lithics, with red, light and dark green, brown grains, including feldspar, chert; moderate calcareous; estimate fair porosity and permeability; oil indicators masked by oil based mud contamination. 15025 Tuffaceous claystone = medium to brownish gray; soft to slightly firm; moderate hydrophilic; black to platy, some flaky; moderately organic, grading to carbonaceous shale; gritty texture grading to fine sand; slightly calcareous. ~ EPOCH 49 ~ ~ UNOCALt) A-15RD CAlLY ACTIVITY SUMMARY 12/05/01 Epoch mudloggers arrived on location 1 pm on Monday, December 3; Epoch to log on @ 1074' when drilling out of 13 3/8" casing shoe. 12/06/01: 1074'-1106' Drill cement from 811 to 853'; losing mud over shakers; condition and build mud; drill cement from 853 to 1074'; drill from 1074 to 1083'; change mud system to recover cuttings in safe guard tank; orient tool; slide from 1083 to 1106'. 12/07/01: 1106'-1463' Drill and slide from 1106 to 1184'; perform fit; thaw choke line; drill and slide from 1184 to 1340'; perform sheen test while circulating 9 spm-failed; switch cuttings to safe guard tank; drill and slide from 1340 to 1463'. 12/08/01: 1463'-1849' Drill and slide from 1463 to 1653'; circulate and clean hole; wiper trip to shoe; work pipe and pump 9 spm while waiting on safe guard tanks; trip to bottom washing down last stand; drill and slide from 1653' t01849'; circulate out oil contaminated cuttings. 12/09/01: 1849' Finish circulating at 1849' and trip to shoe; swap out oil contaminated mud transferring old mud to Grayling Platform; building new mud and new mud system, for easier disposal. 12/10/01: 1849' -2182' Finish building new mud system; displace mud in hole and build volume in mud pits; drill ahead, rotating and sliding from 1850' to 2182'. 12/11/01: 2182'-311 0' Drill ahead, rotating and sliding, from 2182 to 3110'. 12/12/01: 3110' -3593' Drill ahead, rotating and sliding, from 3110' to 3593'; trip out of hole for Bit #2; test BOPs. 12/13/01: 3593' -4046' Finish testing BOPs; make up and trip in hole with new BHA, including new PDC bit #2 and new mud motor; trip in hole to 2167, and wash and ream 1 stand to 2260', maximum 394 units of gas; trip in to 2980' and work pipe through tight spot; trip to bottom, washing and reaming, maximum 1050 units of gas; drill ahead, rotating and sliding from 3594' to 4046'. 12/14/01 :4046'-4403' Drill ahead, rotating and sliding, from 4046' to 4403', diverting cuttings to safeguard tanks beginning at4114' after oil show. 12/15/01 :4403'-4419' [;I EPOCH 50 ~ ~ UNOCAL8 A-15RD Drill ahead, rotating and sliding, from 4403 to 4419', continuing to divert cuttings to Safe Guard tanks, trip out of hole for new bit #3 and new mud motor, trip in hole, ream and wash last stand, prep to drill. 12/16/01: 4419'-5195' Drill ahead, rotating and sliding, from 4419 to 5195'. 12/17/01: 5195'-5451' Drill ahead, rotating and sliding, from 5195 to 5451', trip out of hole to shoe, back reaming, maximum 29 units of gas, circulate casing clean, maximum 50 units of gas, pull out of hole for bit #4 and new mud motor, change out damaged 5" heavy weight drill pipe. 12/18/01: 5451 '-6142' Trip in hole with new bit #4 and new mud motor, wash and ream to bottom, maximum 553 units of gas; rotate and slide from 5451 to 6142'. 12/19/01: 6142'-6744' Drill ahead, rotating and sliding, from 6142' to 6744'. 12/20/01: 6744'-7033' Drill ahead, rotating and sliding from 6744 to 7033'; circulate bottoms up and clean hole while working pipe; trip out of hole, circulating and working pipe through tight spots, maximum 313 units of gas. 12/21/01: 7033' Finish trip out of hole, circulating and working pipe through tight spots, maximum 185 units of gas; test BOPs; make up MWD tools; trip in hole for MAD pass. 12/22/01: 7033' Finish trip in hole to MADD pass logging depth, 5574', washing in last 14 stands, maximum 70 units of gas; log hole up to casing shoe while pulling pipe and circulating, maximum 85 units of gas; circulate bottoms up at shoe, maximum 10 units. 12/23/01: 7033'-7092' Trip out of hole from shoe and pick up new BHA with new bit #5 and new mud motor; trip in to shoe and test MWD, work on brakes, and cut drill line; trip in hole to 7033', washing and reaming through tight spots; drill from 7034 to 7092'. 12/24/01: 7092' -7486' Drill from 7092' to 7473'; pump high viscosity sweep; pull out of hole to 6535'; trip back in hole to 7473'; drill from 7473 to 7486'. 12/25/01: 7486' -7910' Drill ahead, rotating and sliding, from 7486' to 7910'. 12/26/01 : 7910' Circulate out at 7910', pump sweep, and clean hole, maximum 65 units of gas; trip out of hole to shoe, back reaming and working through tight spots, maximum 20 units of gas; trip to bottom washing through tight spots; circulate bottoms up and clean hole, maximum 515 units of gas; circulate and condition 8 hours on bottom, maximum 135 units of gas; begin trip out of hole. ~ EPOCH 51 ~ ~ UNOCALe A-15RD 12/27/01: 7910' Finish trip out of hole; rig up Schlumberger and run in hole with open hole logs; log from 5900' to casing shoe; test BOP's. 12/28/01 : 7910' Finish test BOPs, and continue wireline logging with Schlumberger, collecting formation fluid samples and pressures with MDT tool, tripping in wireline tool with drill pipe. 12/29/01: 7910' Finish running MDT tool; trip out of hole; rig down Schlumberger; make up BHA and run in hole, reaming and circulating through tight spots; circulate bottoms up at 3500',4459' and 5507'. Max trip gas at report time: 150 units at 4459'. 12/30/01: 7910' Continue tripping in hole to approximately 6835', washing and reaming; work pipe due packing off with coal cavings; circulate while working pipe and back reaming out of hole 5 stands, maximum 365 units of gas; continue circulating, working pipe and cleaning hole until gas to 75 units; continue pulling out of hole to 5450', working pipe through tight spots; trip in hole; back ream out of hole to 6150'; max gas at report time-614 units while circulating at 6228'. 12/31/01:7910' Work pipe at 6228' while working on pump suctions; trip out to stand 48 and clean pits; wash and ream to 6835', maximum of 268 units of gas; packing off, break stand and work through tight spot; continue working slowly into hole working pipe, circulating and back reaming through tight spots to 6850' at report time; large amounts of coal coming over shakers including many of baseball size and larger; max gas at report time-460 units at 6595' and 457 units at 6822'. 01/01/02: 791 0'-8216' Continue working slowly into hole working pipe and reaming 6850 to 7910'; maximum of 285 units of gas; drill ahead, rotating and sliding, from 7910 to 7951; lay back stand and change shaker screens; drill ahead, rotating and sliding from 7951 to 8216'. 01/02102: 8216' -8465' Drill ahead, rotating and sliding, from 8216 to 8465'; circulate and pump and circulate out sweep; short trip to 5500'; trip back in hole, circulating and working pipe through tight spots to 6850' at report time; max gas at report time-45 units at 6820'. 01/03/02: 8465' Continue working pipe at 6850' and pull back 3 stands and circulate and clean hole of coal slough, maximum 415 units; wash and ream to 6853' and slide 15' through tight spot; work pipe and circulate, survey - dropped 1.8 degrees from previous survey, and continue circulating, maximum 145 units of gas; pump sweep and circulate; pull out of hole to 5500', back reaming, maximum 470 units of gas; trip in to 6855'; spot Soltex pill to stabilize coal; trip out of hole to make a run with a 12 %" hole opener. 01/04/02: 8465' Run in with 12 %" hole opener and BHA to shoe; cut drill line; run in hole reaming through tight spots down to 6837'; maximum 6115 units of gas; work pipe while reaming to avoid [1 EPOCH 52 ~ ~ UNOCAL8 A-15RD sidetrack and work through tight spots down to 6932'; maximum of 385 units of gas; run to bottom, reaming through tight spots; circulate 1.5 times bottoms up, maximum 160 units of gas; pull up to 8050' and pump sweep, maximum 15 units; begin wiper trip out of hole to 5500'. 01/05/02: 8465' Finish trip out of hole to 5500'; trip to bottom washing through tight spots; circulate and pull 3 stands; pump sweep and circulate out, maximum 35 units of trip gas; pull out of hole to 6930' and spot pill 730 strokes, maximum 21 units of gas; pull out of hole 2 stands and pump dry job; begin pull out of hole for casing run. Epoch completes partial rig down for standby: powers down equipment, caps hydrogen and span gas bottles, and removes gas trap. 01/06/02: Standby 01/07/02: Standby 01/08/02: Standby 01/09/02: Standby 01/10/02: Standby 01/11/02: Standby 01/12/02: 8465' Epoch mudloggers arrived on location at 5:30 pm after 6 days standby, 1/6/02 thru 1/11/02. Rig picked up BHA and began tripping in hole. 01/13/02: 8465'-8481' Finish running in hole and drill float, cement, and shoe down to 8157'; wash and ream down to 8465', maximum 520 units of gas, circulate hole clean; pull up into shoe and displace water based mud with oil based in pits; trip in to bottom and drilled ahead from 8465' to 8481'. 01/14/02: 8481'-8769' Drill ahead from 8481' to 8490', and circulate out; pull out 3 stands to shoe and test formation integrity: P.I.T. = 10.4 E.M.W.; continue to build volume and weight up mud in pits; trip in and drill ahead to 8494', maximum 8 units of trip gas; pull out of hole 3 stands to shoe and work on shakers; drill ahead from 8494' to 8769', circulate and condition hole; pull out 33 stands to 5870'; service top drive and draw works. 01/15/02: 8769'-9140' Finish service top drive and draw works; pick up and run in hole with drill pipe; drill ahead from 8769' to 9140'. 01/16/02: 9140'-9180' Drill ahead from 9140' to 9158'; circulate and trip out of hole; pick up new bit #8 and new mud motor and trip in hole; wash and ream last two stands to bottom and drill ahead, rotating and sliding, from 9158' to 9180'; shakers down; pull out to shoe while troubleshooting shakers; draw works chain breaks during trip to shoe; shakers back online. [~ EPOCH 53 ~ ~ UNOCAL8 A-15RD 01/17/02: 9180'-9668' Finish working on draw works; run in hole to 9072' and wash and ream to bottom, trip gas 15 units; pull off bottom and work on brakes; drill ahead from 9179' to 9326', slide 9326' to 9351', drill ahead from 9351' to 9414'; slide from 9414' to 9444'; drill ahead from 9444' to 9668'. 01/18/02: 9668'-10213' Drill ahead from 9668' to 9943; both pumps down; repair pumps; drill ahead from 9943 to 10213'. 01/19/02: 10213'-10537' Drill ahead, rotating and sliding, from 10213' to 10537'; circulate out and pull 5 stands; pump dry job and pull out of hole; test BOPs. 01/20/02: 10537-10577' Finish testing BOPs; pick up BHA with new bit #9 and new mud motor; test MWD tool; trip in hole 60 stands and cut drill line; work on brakes for draw works; run in hole to 10537' reaming last 53';slide from 10537' to 10559'; drill ahead from 10559' to 10577'. 01/21/02: 10577'-11050' Drill ahead from 10577' to 10923'; slide from 10923' to 10930'; drill ahead from 10930' to 10953'; slide from 10953' to 10994'; drill ahead from 10994 to 11050'. 01/22/02: 11050' -11357' Drill ahead from 11050' to 11087'; slide from 11087' to 11139'; drill ahead from 11139' to 11248'; change out swivel packing on top drive; drill ahead from 11248' to 11357'; lose pump pressure; pull out of hole wet looking for washout; found washout at 8786'; prepare to run in hole. 01/23/02: 11357'-11519' Run in hole from 8786', washout, to bottom; drill ahead, trip gas 6 units, from 11357' to 11431'; lay down stand from derrick and remove actuator valve from flow line; slide from 11431' to 11516', and rotate to 11519'; circulate bottoms up; pump dry job; pull out of hole to shoe; replace low drive chain on draw works; run in hole 7 stands; pull out of hole for new bit #10 and LWD tools. 01/24/02: 11519'-11756' Pick up and run in with BHA including new bit #10, new mud motor, and LWD tools; run in hole reaming to bottom last 102 feet; trip gas 25 units, drill ahead, mostly sliding, from 11519' to 11756'. 01/25/02: 11756'-12077' Drill ahead, rotating and sliding, from 11756' to 12077'. 01/26/02: 12077' -12335' Drill ahead, rotating and sliding, from 12077' to 12335'. 01/27/02: 12335'-12428' [1 EPOCH 54 r", ~ UNOCAL8 A-15RD Drill ahead, picking up singles at connections, from 12335' to 12428'; circulate bottoms up after drilling break to confirm drilling sand (Hemlock); pull out three singles and lay down; MADD pass out of hole from 12072' to 11435', maximum 26 units of gas. 01/28/02: 12428' MADD pass out of hole from 11435' to 11030', maximum 8 units of gas; circulate out and pump dry job, maximum 10 units of gas; pull out of hole; test BOP. 01/29/02: 12428' Finish testing BOPs; pick up new BHA with new bit #11 and high angle mud motor, 1.83 degrees; trip in hole 56 stands; lay down 24 joints of 5" drill pipe; cut drill line; pick up and run in with 39 joints of drill pipe to 8609', washing and reaming and working pipe through tight spots below 12 X" hole @ 8465', maximum 48 units of gas; wash and ream to 9110', maximum 26 units of gas; pull out of hole for new bit and lower angle mud motor. 01/30/02: 12428' Finish pull out of hole; pick up and run in hole with new bit #12 and smaller angle mud motor, 1.50 degrees; run in hole to 9180'; run in hole working pipe, and washing and reaming, from 9180' to 11865', maximum 29 units of gas; run in hole to 12270'; pull out of hole to 12259'; circulate and work pipe; back ream and pump out of hole to 11975'; stuck pipe; repair mud line; continue to work and attempt to free stuck pipe. 01/31/02: 12428' Free stuck pipe pull 2 stands and circulate and condition hole; pull out of the hole; lay down BHA; pick up 800' of 27/8" tubing; run in hole. 02/01/02: 12428' Run in hole with tubing; work on brakes; trouble shoot draw works; continue in hole; circulate at the shoe; continue in hole, slowly through open hole; circulate at 9143'; continue in hole; pressure test Dowell lines to 3000 psi; pump 11 bbls cement; chase with rig pumps. BEGIN DATA FOR A15RDST1 02/02/02: 10189' Continue cementing; pull up hole to 11499'; pump 5 bbls OBM; pull up hole to 11128'; circulate bottoms up, 9 BPM @ 2100 psi; pump 20 bbl viscous pill; pull out of hole to 10980'; circulate bottoms up; pump cement mix; pull up hole to 9700'; circulate bottoms up and monitor well for 15 minutes; static; circulate dart in place and pump pill; pull out of hole; notice cement in tool joints; break and clean tool joints; lay down 2 7/8" tubing; rig down GBR; clean rig floor; trip in hole 50 joints; break every joint cleaning away cement. 02/03/02: 10189' Continue pulling out of hole breaking every joint, cleaning away cement; pick up BHA with new bit #13 and mud motor; test MWD tool; trip in hole, rattling drill pipe for cement and breaking every 1500', to shoe; clean floor for brake change; hang blocks; cut drill line. 02/04/02: 10189'- [~ EPOCH 55 ~. ~. UNOCAL8 A-15RD Finish cut drill line and working on brakes for draw works; slip drill line and trip in hole to top of cement @ 10189'; drill cement down to 10430'; work pipe to begin sidetrack; drill ahead, rotating and sliding, from 10430' to 10464'. 02/05/02 Drill ahead, rotating and sliding, from 10464' to 10861'. 02/06/02 Drill ahead, rotating and sliding, from 10861' to 11053'. 02/07/02 Drill ahead, rotating and sliding, from 11053' to 11206'; pump dry job and trip out of hole; lay down BHA; begin BOP test. 02/08/02 Finish BOP test; pick up BHA with new bit #14 and mud motor; trip in hole; wash and ream from 11154' to 11206'; drill ahead, 48 units of trip gas, rotating and sliding, from 11206' to 11343'. 02/09/02 Drill ahead, rotating and sliding, from 11343' to 11678'. 02/10/02 Drill ahead, rotating and sliding, from 11678' to 11853'; circulate bottoms up; pump dry job; trip out of hole to BHA. 02/11/02 Trip in with new bit #3 and new mud motor; wash and ream two stands to bottom; drill ahead, rotating and sliding, from 11853' to 12013'. 02/12/02 Drill ahead, rotating and sliding, from 12013' to 12271'. 02/13/02 Drill ahead, rotating, from 12271' to 12382'; circulate bottoms up; MADD pass out of hole. 02/14/02 Epoch mud loggers leave on standby 7:00am Feþruary 14. Partial rig down of equipment. 02/15/02 to 2/16/02 Standby. 02/17/02 Epoch mud logger arrived on location 4:00 pm February 17, after standby February 15-16, while drill floor picking up drill pipe; finish picking up drill pipe and trip in hole to tag cement @ 12275'; test casing and service top drive; drill cement and float equipment from 12275' to 12297'. . 02/18/02 [j EPOCH 56 .~. /-". UNOCAL8 A-15RD Finish drilling float, cement, and shoe from 12297' to 12382'; drill to 12402' and test formation integrity; drill ahead from 12402' to 12415'; trip out of hole; change BHA and rerun bit number 4; trip in hole. 02/19/02 Finish trip in hole; drill ahead, mostly sliding, from 12415' to 12468'; pump dry job and pull out of hole; pick up new bit #6; trip in hole to shoe; cut and slip drill line; finish trip in hole. 02/20/02 Begin drill ahead, 2 units of trip gas, mostly sliding, from 12468' to 12624'; pull out of hole to shoe; pump dry job; trip out of hole. 02/21/02 Finish trip out of hole and pick up new bit #7 and new mud motor; trip in hole to shoe; trip to bottom taking five check point surveys; drill ahead, 2 units of trip gas, rotating and sliding, from 12624' to 12797'. 02/22/02 Drill ahead, rotating and sliding, from 12797' to 13055'; pump dry job; pull out of hole for new bit #8; lay down BHA. 02/23/02 Lay down BHA.; test BOP's; pick up BHA with new bit #8 and new mud motor; unable to load source on ADN tool and laid back same; ran in hole with 3 W' drill pipe and picked up and ran in with 18 joints of 3 W' drill pipe; ran in hole to bottom washing in last stand and back reaming back to tool joint; washed to bottom and drilled ahead, 4 units of trip gas, rotating and sliding, from 13055' to 13162'. 02/24/02 Drilled ahead, rotating and sliding, from 13162' to 13358'; circulate bottoms up; pull out of hole to shoe; pump dry job; pull out of hole for new bit #9. 02/25/02 Pick up new BHA with new bit #9, new mud motor, and ADN tool; run in hole to 12538'; pipe stuck, work pipe and free pipe; pull out of hole changing BHA to less stiff assembly and laying down ADN tool; trip in hole with same bit #9 to shoe; cut and slip drill line; finish tripping in hole. 02/26/02 Wash and ream 110' to bottom, 50 units of trip gas; drill ahead, rotating and sliding, from 13355' to 13516'. 02/27/02 Drill ahead, rotating and sliding, from 13516' to 13620'; circulate bottom up 1.5 times; pull out of hole to shoe; pump dry job; pull out of hole. 02/28/02 Pull out of hole; work stuck pipe; free pipe; pull out of hole; lay down BHA; pick up new BHA with bit #10, new mud motor, and ADN tool; run in hole; wash through tight spots in 7" casing, maximum 34 units of gas; trip in down to 13280' to begin MADD pass. [j EPOCH 57 ,~ ,~ UNOCAL8 A-15RD 03/01/02 Run MADD pass from 13280' to 12280' at 300' per hour; run in hole to 12700'; trench for open hole sidetrack; time drill from 12700' to 12722'; slide from 12722' to 12749'. 03/02/02 Drill ahead, sliding and rotating, from 12749' to 13063'; circulate out and clean hole; run MADD Pass 13063' to 12954'. 03/03/02 Continue MADD Pass from 12954' to 12383; circulate bottom up 1.5 times while working pipe; drop dart; pump high viscosity sweep; circulate sweep around plus one bottom up; pull out of hole to top of liner, no problems; pump dry job; pull out of hole; lay down BHA; unload source; download data from logging tools; test BOP's; pick up BHA with new bit #11 and mud motor; load source; run in hole. 03/04/02 Finish tripping in hole; maximum trip gas 3 units; drill ahead, rotating and sliding, from 13063' to 13281 '. 03/05/02 Drill ahead, rotating and sliding, from 13281' to 13369'; circulate bottom up twice; MADD pass section drilled during latest bit run; pull out of hole to shoe; pump high viscosity sweep around once; circulate bottom up one and a half times; pull out of hole; change out nuclear source and bit. 03/06/02 Trip in hole with new bit #12, washing last 100'; maximum 8.0 units of trip gas; drill ahead, sliding and rotating, from 13369' to .13507'. 03/07/02 Drill ahead, sliding and rotating, from 13507' to 13733'; MADD pass out of hole to 13359'; pull out of hole. 03/08/02 Finish pulling out of hole; lay down BHA, ADN tool; pick up new bit#13 and mud motor; pick up six stands 3.5" drill pipe; run in hole; cut and slip drill line; orientate tool for entrance into open hole sidetrack; wash and ream from 12700' to 13406'; begin drilling new hole from 13406' to 13464' (A-15RDST1L 1A). 03/09/02 Drill ahead, sliding and rotating, from 13464' to 13630'. 03/10/02 Drill ahead, sliding and rotating, from 13630' to 13660'; circulate bottom up; pull out of hole to 12700' and align tool face as to reacquire A-15RDST1 L 1 A; run back in hole; circulate bottom up; pull out of hole; lay down BHA; pick up new BHA with bull nose and 2 7/8" tubing; run in hole to check if hole can be acquired with dummy liner. 03/11102 [:I EPOCH 58 ~ ,,--.., UNOCAL8 A-15RD Run in hole to bottom with dummy BHA; circulate bottom up; pull out to shoe; pump dry job; pull out of hole; pick up drilling BHA with new bit #14, mud motor and ADN tool; run in hole. Drill from 13660' to 13685' = 25'. 03/12/02 Epoch mud logging crew change at 1 :00 pm. Drill ahead, mostly sliding, from 13685' to 13995'. 03/13/02 Drill ahead from 13995' to 14021'. Circulate out. Trip for new bit No.15. SMITH 6" XR20HDTGPD/MK1292 w/3x12's. Drill from 14021' to 14030'. 03/14/02 Drill ahead from 14030' to 14269'. Circulate out. Trip for the new bit No. 16, Hughes STX- 20DX2/ZM64JG w/3x12's. 03/15/02 Trip in to hole. Drill from 14269' to 14340'. 03/16/02 Drill ahead from 14340' to 14530'. 03/17/02 Drill and slide from 14530' to 14558'. Trip for the new bit No. 17; Hughes STXDX2 w/3x12's. 03/18/02 Drill ahead from 14558' to 14838'. Trip for the bit No. 18, SMITH XR20HTGPD w/3x12's. 03/19/02 Drilling from 14838' to 14895'. 03/20/02 Continue drilling from 14895' to 15042'. TD at 15042' 03/21/02 Rig down. Epoch mud loggling crew departs at 5:15am. [=I EPOCH 59 ~. ~ UNOCALe A-15RD SURVEY SUMMARY MD Inti Azim TVD VSec NS EW DLS Course Closure CIAzim (ft) (O) (O) (ft) (ft) (ft) (ft) ¡a/100ft) (ft) (ft) (O) 873.00 15.25 340.00 863.70 -98.32 91.10 -37.10 0.00 0.00 98.36 337.84 1073.00 19.97 340.91 1054.27 -158.64 148.12 -57.28 2.36 200.00 158.81 338.86 1110.19 18.56 341.34 1089.38 -170.87 159.73 -61.25 3.81 37.19 171.07 339.02 1198.18 15.07 342.37 1173.60 -196.19 183.91 -69.20 3.98 87.99 196.50 339.38 1290.79 10.81 344.86 1263.83 -216.76 203.78 -75.11 4.64 92.61 217.18 339.77 1384.51 6.27 344.55 1356.49 -230.52 217.20 -78.77 4.84 93.72 231.04 340.07 1477.28 3.71 341.97 1448.90 -238.52 224.94 -81.05 2.77 92.77 239.10 340.18 1571.01 3.21 339.32 1542.46 -244.15 230.28 -82.92 0.56 93.73 244.75 340.20 1662.92 2.03 32.12 1634.28 -247.64 234.06 -82.96 2.78 91.91 248.33 340.48 1756.52 4.37 92.93 1727.75 -246.96 235.29 -78.52 4.08 93.60 248.04 341.55 1850.96 7.02 107.11 1821.72 -241.56 233.40 -69.41 3.16 94.44 243.50 343.44 1943.99 9.89 115.42 1913.74 -231.79 228.30 -56.75 3.35 93.03 235.25 346.04 2038.09 13.42 124.35 2005.89 -216.39 218.67 -40.43 4.20 94.10 222.37 349.52 2131.00 16.87 129.60 2095.56 -195.17 203.98 -21.14 3.99 92.91 205.08 354.08 2225.67 20.75 132.37 2185.16 -167.53 183.92 1.85 4.20 94.67 183.93 0.58 2318.55 24.63 136.86 2270.84 -134.20 158.70 27.25 4.57 92.88 161.02 9.74 2413.62 28.53 141.99 2355.86 -93.48 126.34 54.79 4.76 95.07 137.70 23.45 2504.81 32.79 143.05 2434.29 -48.31 89.43 83.06 4.71 91.19 122.05 42.88 2596.04 37.32 142.65 2508.95 2.66 47.68 114.70 4.97 91.23 124.21 67.43 2689.57 40.74 141.50 2581.59 59.76 1.24 150.91 3.74 93.53 150.92 89.53 2781.52 40.91 141.21 2651.17 117.87 -45.71 188.45 0.28 91.95 193.91 103.63 2873.59 41.14 140.92 2720.63 176.21 -92.72 226.43 0.32 92.07 244.68 112.27 2970.38 40.98 140.79 2793.61 237.52 -142.02 266.56 0.19 96.79 302.04 118.05 3063.42 40.16 139.01 2864.29 295.59 -188.31 305.53 1.52 93.04 358.90 121.65 3155.92 39.46 140.39 2935.35 352.37 -233.47 343.84 1.22 92.50 415.61 124.18 3249.69 39.42 140.59 3007. 76 409.71 -279.43 381.74 0.14 93.77 473.08 126.20 3342.98 38.12 140.67 3080.50 465.99 -324.59 418.79 1.39 93.29 529.85 127.78 3436.53 37.07 142.49 3154.62 521.20 -369.29 454.26 1.63 93.55 585.43 129.11 3533.48 37.50 142.67 3231.76 578.28 -415.94 489.95 0.46 96.95 642.69 130.33 3599.87 37.29 143.15 3284.50 617.52 -448.10 514.26 0.54 66.39 682.10 131.07 3693.80 39.02 142.71 3358.36 674.00 -494.40 549.25 1.86 93.93 738.98 131.99 3786.77 38.92 142.72 3430.64 730.86 -540.92 584.67 0.11 92.97 796.51 132.77 3881.03 38.79 143.50 3504.05 788.45 -588.21 620.16 0.54 94.26 854.75 133.49 3975.10 39.00 143.65 3577.26 846.09 -635.74 655.23 0.24 94.07 912.96 134.13 4066.31 39.55 143.98 3647.87 902.49 -682.34 689.32 0.65 91.21 969.92 134.71 4159.45 39.61 144.14 3719.66 960.50 -730.39 724.15 0.13 93.14 1028.53 135.25 4252.36 39.60 141.25 3791.24 1018.08 -777.49 760.04 1.98 92.91 1087.27 135.65 4346.38 40.05 139.82 3863.45 1076.06 -823.97 798.32 1.09 94.02 1147.27 135.91 4440.17 38.79 139.13 3935.91 1133.09 -869.24 837.01 1.42 93.79 1206.72 136.08 4534.31 38.48 138.83 4009.44 1189.23 -913.59 875.59 0.38 94.14 1265.42 136.22 ~ EPOCH 60 ~ ~ UNOCAL8 A-15RD MD Inti Azim TVD VSec NS EW DLS Course Closure CIAzim (ft) n {OJ (ft) (ft) (ft) (ft) (o/1O0ft) (ft) (ft) (O) 4627.29 38.05 138.97 4082.45 1244.21 -956.98 913.44 0.47 92.98 1322.94 136.33 4720.44 37.11 140.26 4156.27 1298.65 -1000.24 950.25 1.32 93.15 1379.66 136.47 4813.24 36.14 140.83 4230.75 1351.96 -1042.99 985.43 1.11 92.80 1434.89 136.63 4908.03 37.07 142.01 4306.84 1406.61 -1087.18 1020.67 1.23 94.79 1491.22 136.81 5001.05 37.15 143.80 4381.02 1461.22 -1131.94 1054.52 1.16 93.02 1547.03 137.03 5094.97 37.03 144.19 4455.94 1516.58 -1177.76 1087.82 0.28 93.92 1603.26 137.27 5187.28 36.32 143.86 4529.98 1570.48 -1222.38 1120.20 0.80 92.31 1658.03 137.50 5285.72 36.44 143.11 4609.23 1627.43 -1269.30 1154.95 0.47 98.44 1716.11 137.70 5380.23 36.82 141.50 4685.08 1682.17 -1313.92 1189.43 1.09 94.51 1772.32 137.85 5441.26 37.06 141.40 4733.86 1717.64 -1342.60 1212.28 0.41 61.03 1808.92 137.92 5536.51 39.30 139.97 4808.73 1774.36 -1388.14 1249.60 2.53 95.25 1867.73 138.01 5630.32 40.42 139.47 4880.74 1832.01 -1434.00 1288.47 1.24 93.81 1927.83 138.06 5722.81 40.53 139.65 4951.09 1889.53 -1479.69 1327.41 0.17 92.49 1987.84 138.11 5813.81 41.14 139.93 5019.94 1946.61 -1525.14 1365.83 0.70 91.00 2047.32 138.15 5907.43 41.44 140.32 5090.29 2005.97 -1572.55 1405.43 0.42 93.62 2109.06 138.21 5999.98 42.08 140.20 5159.32 2065.24 -1619.94 1444.84 0.70 92.55 2170.66 138.27 6094.50 41.49 141.32 5229.80 2125.95 -1668.72 1484.68 1.01 94.52 2233.58 138.34 6187.91 41.53 142.38 5299.75 2185.92 -1717.40 1522.92 0.75 93.41 2295.38 138.43 6282.53 41.43 144.12 5370.64 2246.99 -1767.61 1560.42 1.22 94.62 2357.83 138.56 6376.55 40.48 145.39 5441.65 2307.39 -1817.94 1595.98 1.34 94.02 2419.10 138.72 6468.41 40.20 147.05 5511.67 2365.95 -1867.36 1629.04 1.21 91.86 2478.07 138.90 6560.99 39.67 147.96 5582.66 2424.69 -1917.48 1660.97 0.85 92.58 2536.84 139.10 6656.10 38.84 148.69 5656.30 2484.31 -1968.69 1692.58 1.00 95.11 2596.26 139.31 6749.79 38.71 148.64 5729.35 2542.48 -2018.81 1723.09 0.14 93.69 2654.17 139.52 6844.16 39.11 148.23 5802.78 2601.20 -2069.31 1754.12 0.50 94.37 2712.75 139.71 6938.88 38.44 149.77 5876.62 2660.05 -2120.15 1784.67 1.24 94.72 2771.30 139.91 7032.90 37.65 152.33 5950.67 2717.75 -2170.84 1812.72 1.88 94.02 2828.17 140.14 7128.34 37.49 153.90 6026.32 2775.85 -2222.74 1839.04 1.02 95.44 2884.90 140.40 7223.77 37.45 157.18 6102.07 2833.89 -2275.57 1863.07 2.09 95.43 2940.96 140.69 7322.89 37.32 159.83 6180.83 2894.01 -2331.55 1885.12 1.63 99.12 2998.30 141.04 7411.14 36.93 160.88 6251.20 2947.13 -2381.71 1903.03 0.84 88.25 3048.62 141.37 7603.74 35.45 163.05 6406.64 3060.26 -2489.82 1938.27 1.02 192.60 3155.33 142.10 7697.52 36.43 162.97 6482.56 3114.92 -2542.46 1954.35 1.05 93.78 3206.80 142.45 7789.67 36.47 161.07 6556.69 3169.38 -2594.53 1971.25 1.23 92.15 3258.44 142.77 7883.50 36.68 161.15 6632.04 3225.08 -2647.43 1989.35 0.23 93.83 3311.55 143.08 7979.47 37.15 156.30 6708.79 3282.63 -2701.10 2010.26 3.07 95.97 3367.06 143.34 8164.04 39.39 158.00 6853.69 3396.91 -2806.45 2054.61 1.34 184.57 3478.16 143.79 8259.68 39.84 157.85 6927.37 3457.87 -2862.96 2077.53 0.48 95.64 3537.32 144.03 8356.51 39.71 157.49 7001.79 3519.80 -2920.26 2101.07 0.27 96.83 3597.56 144.27 8450.88 40.41 157.49 7074.01 3580.52 -2976.37 2124.32 0.74 94.37 3656.71 144.48 [:8 EPOCH 61 ~. /~ UNOCAL8 A-15RD MD Inti Azim TVD VSec NS EW DLS Course Closure CIAzim (ft) n (O) (ft) (f!) (ft) (ft) (°/1 OOft) (ft) (ft) n 8544.62 40.12 156.73 7145.54 3641.10 -3032.19 2147.88 0.61 93.74 3715.85 144.69 8639.32 38.25 156.71 7218.94 3700.92 -3087.15 2171.53 1.97 94.70 3774.39 144.88 8734.63 37.78 155.90 7294.03 3759.62 -3140.90 2195.12 0.72 95.31 3831.94 145.05 8826.35 36.46 159.18 7367.17 3814.94 -3192.02 2216.28 2.59 91.72 3885.99 145.23 8919.70 35.77 161.33 7442.59 3869.82 -3243.80 2234.87 1.55 93.35 3939.15 145.43 9013.80 35.99 162.02 7518.83 3924.71 -3296.15 2252.21 0.49 94.10 3992.12 145.66 9105.16 36.11 161.39 7592.70 3978.23 -3347.20 2269.09 0.43 91.36 4043.82 145.87 9203.33 35.80 161.91 7672.16 4035.61 -3401.91 2287.23 0.44 98.17 4099.32 146.09 9296.38 34.98 162.07 7748.02 4089.22 -3453.15 2303.90 0.89 93.05 4151.17 146.29 9389.49 35.57 161.96 7824.04 4142.72 -3504.30 2320.50 0.64 93.11 4202.95 146.49 9482.15 37.63 161.25 7898.42 4197.72 -3556.72 2337.94 2.27 92.66 4256.31 146.68 9573.30 37.34 160.79 7970.75 4252.99 -3609.17 2355.98 0.44 91.15 4310.07 146.86 9667.44 37.35 160.52 8045.59 4309.92 -3663.05 2374.90 0.17 94.14 4365.56 147.04 9761.68 36.41 160.88 8120.97 4366.30 -3716.43 2393.59 1.02 94.24 4420.53 147.22 9855.69 35.97 160.78 8196.84 4421.63 -3768.86 2411.82 0.47 94.01 4474.50 147.38 9954.14 36.12 160.05 8276.45 4479.40 -3823.44 2431.24 0.46 98.45 4530.96 147.55 10049.39 35.73 160.17 8353.58 4535.16 -3875.99 2450.25 0.42 95.25 4585.52 147.70 10143.55 34.14 160.26 8430.77 4588.95 -3926.72 2468.50 1.69 94.16 4638.17 147.84 10234.92 32.82 160.78 8506.98 4639.21 -3974.24 2485.31 1.48 91.37 4687.36 147.98 10329.90 34.31 161.90 8586.12 4691.50 -4023.99 2502.10 1.70 94.98 4738.46 148.13 10425.06 36.36 162.44 8663.74 4746.24 -4076.38 2518.95 2.18 95.16 4791.87 148.29 10519.96 37.30 161.95 8739.70 4802.81 -4130.54 2536.35 1.04 94.90 4847.11 148.45 10613.41 38.23 158.89 8813.58 4859.87 -4184.45 2555.54 2.24 93.45 4903.10 148.59 10707.29 37.85 158.07 8887.52 4917.68 -4238.26 2576.75 0.67 93.88 4960.09 148.70 10803.43 37.72 157.25 8963.50 4976.56 -4292.75 2599.14 0.54 96.14 5018.29 148.81 10897.51 37.59 156.78 9037.99 5034.03 -4345.66 2621.59 0.34 94.08 5075.18 148.90 10991.89 39.85 159.40 9111.62 5093.02 -4400.43 2643.58 2.96 94.38 5133.44 149.00 11088.97 39.94 160.30 9186.10 5155.15 -4458.88 2665.03 0.60 97.08 5194.61 149.13 11180.49 43.51 161.57 9254.40 5215.84 -4516.45 2684.90 4.01 91.52 5254.23 149.27 11276.85 43.23 161.86 9324.45 5281.71 -4579.27 2705.66 0.36 96.36 5318.87 149.42 11369.26 43.06 161.71 9391.87 5344.60 -4639.30 2725.41 0.21 92.41 5380.61 149.57 11465.16 44.51 163.91 9461.11 5410.51 -4702.69 2745.00 2.19 95.90 5445.21 149.73 11549.33 49.58 167.41 9518.46 5471.22 -4762.36 2760.18 6.75 84.17 5504.42 149.90 11642.74 56.20 168.01 9574.78 5544.17 -4835.11 2776.01 7.11 93.41 5575.34 150.14 11732.38 63.65 168.52 9619.67 5619.97 -4911.00 2791.76 8.33 89.64 5649.06 150.38 11823.43 70.18 171.67 9655.36 5701.21 -4993.47 2806.10 7.85 91.05 5727.91 150.67 11919.41 72.39 172.64 9686.16 5788.61 -5083.52 2818.51 2.49 95.98 5812.58 150.99 12016.79 72.81 177.15 9715.29 5876.60 -5176.04 2826.77 4.44 97.38 5897.63 151.36 12108.14 73.34 176.94 9741.88 5958.27 -5263.32 2831.27 0.62 91.35 5976.51 151.72 12205.15 73.55 177.32 9769.53 6045.13 -5356.19 2835.93 0.43 97.01 6060.63 152.10 [:I EPOCH 62 ~ ,~ UNOCAL8 A-15RD MD Inti Azim TVD VSec NS EW DLS Course Closure CIAzim (ft) n n (ft) (ft) (ft) (ft) (o/100ft) (ft) (ft) n 12235.27 73.64 177.28 9778.03 6072.08 -5385.05 2837.29 0.32 30.12 6086.79 152.22 12330.10 74.17 177.50 9804.32 6157.03 -5476.07 2841.44 0.60 94.83 6169.37 152.58 12371.48 74.71 177.35 9815.42 6194.19 -5515.89 2843.23 1.35 41.38 6205.57 152.73 PROJECTED SURVEY TO TOTAL DEPTH ~ Ï>- 12428' 12428.00 74.71 177.35 9830.33 6245.04 -5570.35 2845.75 0.00 56.52 6255.17 152.94 BEGIN SURVEY DATA FOR A15RDST1 AFTER PLUGBACK A15RD 10425.06 36.36 162.44 8663.70 3380.43 -4076.36 2518.97 2.18 95.16 4791.86 148.29 10552.94 39.07 172.53 8764.95 3450.66 -4152.54 2535.66 5.27 127.88 4865.51 148.59 10648.27 43.08 172.50 8836.80 3509.17 -4214.63 2543.82 4.21 95.33 4922.82 148.89 10742.81 43.45 173.26 8905.65 3569.84 -4278.93 2551.85 0.68 94.54 4982.08 149.19 10835.97 44.77 174.82 8972.54 3631.01 -4343.42 2558.57 1.83 93.16 5040.99 149.50 10931.80 46.52 176.63 9039.53 3696.28 -4411.74 2563.66 2.27 95.83 5102.53 149.84 11024.72 . 47.34 177.30 9102.98 3761.38 -4479.52 2567.25 1.03 92.92 5163.03 150.18 11117.76 47.76 177.07 9165.78 3827.30 -4548.09 2570.62 0.49 93.04 5224.29 150.52 11189.83 47.93 177.35 9214.15 3878.60 -4601.46 2573.22 0.37 72.07 5272.09 150.79 11281.24 47.92 178.10 9275.41 3943.92 -4669.25 2575.92 0.61 91.41 5332.66 151.12 11375.27 48.92 177.79 9337.81 4011.71 -4739.54 2578.44 1.09 94.03 5395.52 151.45 11467.94 48.17 178.31 9399.16 4078.67 -4808.96 2580.81 0.91 92.67 5457.71 151.78 11561.70 48.79 180.68 9461.32 4146.80 -4879.14 2581.42 2.00 93.76 5519.94 152.12 11658.20 53.86 183.05 9521.60 4220.59 -4954.41 2578.91 5.59 96.50 5585.42 152.50 11751.73 58.48 186.05 9573.67 4297.33 -5031.82 2572.70 5.61 93.53 5651.37 152.92 11855.65 63.26 189.89 9624.26 4387.65 -5121.65 2560.05 5.62 103.92 5725.84 153.44 11949.64 67.37 191.55 9663.50 4472.94 -5205.54 2544.15 4.66 93.99 5793.99 153.95 12045.12 70.35 193.11 9697.94 4561.96 -5292.52 2525.12 3.47 95.48 5864.05 154.49 12136.09 75.24 197.03 9724.85 4648.78 -5376.38 2502.50 6.77 90.97 5930.26 155.04 12232.70 75.39 194.74 9749.34 4742.14 -5466.26 2476.92 2.30 96.61 6001.26 155.62 12325.84 75.62 195.20 9772.65 4832.28 -5553.37 2453.63 0.54 93.14 6071.26 156.16 12386.20 76.00 194.83 9787.45 4890.78 -5609.89 2438.47 0.87 60.36 6116.95 156.51 12430.25 79.07 194.57 9796.96 4933.77 -5651.49 2427.56 6.99 44.05 6150.81 156.75 12464.13 82.92 194.85 9802.26 4967.22 -5683.85 2419.06 11.39 33.88 6177.22 156.95 12497.28 87.35 194.46 9805.07 5000.23 -5715.80 2410.71 13.41 33.15 6203.38 157.13 12514.24 90.00 194.15 9805.46 5017.19 -5732.23 2406.52 15.73 16.96 6216.89 157.23 12521.04 91.06 194.22 9805.40 5023.99 -5738.82 2404.85 15.62 6.80 6222.33 157.26 12530.92 91.95 194.05 9805.14 5033.86 -5748.40 2402.44 9.17 9.88 6230.23 157.32 12566.90 91.78 193.92 9803.97 5069.82 -5783.29 2393.75 0.59 35.98 6259.11 157.51 12638.56 92.26 193.94 9801.44 5141.43 -5852.80 2376.51 0.67 71.66 6316.89 157.90 12735.73 92.64 194.17 9797.29 5238.51 -5946.98 2352.93 0.46 97.17 6395.53 158.41 12825.79 92.37 194.49 9793.35 5328.47 -6034.15 2330.66 0.46 90.06 6468.61 158.88 12920.07 93.77 193.59 9788.30 5422.61 -6125.48 2307.83 1.76 94.28 6545.80 159.36 13000.21 93.05 194.71 9783.53 5502.60 -6203.05 2288.27 1.66 80.14 6611.66 159.75 13100.49 95.25 196.37 9776.28 5602.53 -6299.40 2261.48 2.75 100.28 6693.04 160.25 [j EPOCH 63 ~ ~ UNOCAL8 A-15RD MD Inti Azim TVD VSec NS EW DLS Course Closure CIAzim (ft) (O) n (ft) (ft) (ft) (ft) (0/100ft) (ft) (ft) (O) 13193.79 91.37 195.02 9770.89 5695.59 -6389.05 2236.29 4.40 93.30 6769.12 160.71 13287.27 92.02 195.62 9768.13 5788.97 -6479.17 2211.60 0.95 93.48 6846.23 161.15 13346.12 93.02 196.31 9765.54 5847.71 -6535.70 2195.43 2.06 58.85 6894.58 161.43 13380.28 90.99 198.77 9764.34 5881.75 -6568.24 2185.14 9.33 34.16 6922.19 161.60 13473.87 88.49 204.25 9764.77 5974.37 -6655.27 2150.84 6.44 93.59 6994.20 162.09 13564.37 80.29 210.98 9773.62 6061.57 -6734.98 2109.19 11.69 90.50 7057.53 162.29 PROJECTED SURVEY TO TOTAL DEPTH ( ~ 12620' 13620.00 80.29 210.98 9783.00 6113.85 -6781.99 2080.96 0.00 55.63 7094.07 162.37 BEGIN SURVEY DATA FOR A15RDST1L 1 12663.16 92.26 197.05 9800.47 4305.70 -5876.49 2369.95 12.63 24.60 6336.38 158.04 12718.78 90.78 197.32 9798.99 4360.75 -5929.60 2353.52 2.70 55.62 6379.60 158.35 12751.46 87.90 198.29 9799.37 4393.15 -5960.71 2343.53 9.30 32.68 6404.86 158.53 12823.35 87.22 199.80 9802.43 4464.55 -6028.60 2320.09 2.30 71.89 6459.64 158.94 12845.73 88.80 199.90 9803.21 4486.82 -6049.64 2312.50 7.07 22.38 6476.56 159.07 12938.85 89.21 201.06 9804.83 4579.60 -6136.86 2279.92 1.32 93.12 6546.69 159.61 13023.39 90.24 201.09 9805.23 4663.92 -6215.74 2249.52 1.22 84.54 6610.28 160.35 13035.33 90.24 201.18 9805.18 4675.83 -6226.88 2245.22 0.75 11.94 6619.29 160.17 13128.67 90.82 203.68 9804.32 4769.05 -6313.15 2209.61 2.75 93.34 6688.66 160.71 13220.15 92.99 202.96 9801.28 4860.42 -6397.10 2173.42 2.50 91.48 6756.23 161.23 13314.49 89.07 203.78 9799.58 4954.64 -6483.64 2136.01 4.25 94.34 6826.46 161.77 13366.87 92.46 202.83 9798.84 5006.97 -6531.73 2115.30 6.72 52.38 6865.71 161.06 i BEGIN SURVEY DATA FOR A15RDST1L1A 13035.33 90.24 201.18 9805.18 4675.83 -6226.88 2245.22 0.75 11.94 6619.29 160.17 13128.67 90.82 203.68 9804.32 4769.05 -6313.15 2209.61 2.75 93.34 6688.66 160.71 13314.49 89.07 203.78 9799.58 4954.67 -6483.67 2136.01 4.25 94.34 6826.46 161.77 13404.92 95.04 205.23 9796.39 5044.97 -6566.44 2099.83 9.25 38.05 6894.01 162.27 13581.48 90.68 210.23 9782.00 5220.69 -6722.85 2019.51 7.16 95.14 7019.62 163.28 13700.42 90.76 218.82 9781.70 5338.07 -6821.19 1952.84 7.23 87.13 7095.23 164.02 13885.91 89.52 227.40 9780.25 5512.80 -6952.97 1822.60 1.84 92.40 7187.89 165.31 13974.85 91.58 227.80 9779.40 5595.04 -7012.94 1756.93 2.36 88.94 7229.67 165.94 14049.30 86.40 227.21 9780.08 5663.76 -7062.88 1701.69 7.00 74.45 7265.19 166.45 14139.07 86.23 227.60 9786.44 5746.82 -7123.80 1636.12 0.47 89.77 7309.27 167.07 14176.49 88.60 227.99 9788.13 5781.34 7148.91 1608.43 6.42 37.42 7327.62 167.32 14224.28 86.06 227.82 9790.36 5825.38 -7180.91 1573.01 5.33 47.79 7351.18 167.64 14241.82 86.22 228.45 9791.54 5841.50 -7192.59 1559.98 3.70 17.54 7359.81 167.76 14332.18 86.26 228.45 9797.46 5924.36 -7252.39 1492.50 0.04 90.36 7404.38 168.37 14426.61 92.75 227.70 9798.28 6011.34 -7315.45 i 1422.28 6.92 94.43 7452.43 169.00 14520.56 88.59 226.97 9797.18 6098.36 -7379.10 1353.22 4.50 93.95 7502.16 169.61 14613.87 89.57 227.36 9798.68 6184.90 -7442.54 1284.80 1.13 93.31 7552.62 170.21 14708.71 86.89 228.61 9801.61 6272.31 -7505.98 1214.38 3.12 94.84 7603.58 170.81 14807.23 88.87 228.58 9805.25 6362.68 -7571.09 1140.54 2.01 98.52 7656.51 171.43 14899.77 92.57 228.23 9804.09 6447.73 -7632.51 1071.35 4.02 92.57 7707.33 172.01 14994.57 92.99 227.40 9799.49 6535.16 -7696.09 1001.19 0.98 92.99 7760.94 172.59 15042.00 92.99 227.40 9797.02 6579.02 -7728.15 966.32 0 92.99 7788.33 172.87 [=I EPOCH 64 ( UNOCAL8 A-15RD MUD SUMMARY ( DEPTHI ASPH- DATE TVD WT VIS PV yp GELS API F iI CK SOL OillWtr SD MBT pH Pm Pf/Mf CI Ca SOL 12/03/01 1073/ 10.0 45 9 18 8/9/11 9.6 1/ 7.5 .01192.49 9.0 0.3 .0510.8 14500 800 12104101 10731 10.1 48 8 20 31518 9.6 11 7.5 01192.49 8.5 0.4 011.0 15500 800 12105101 10731 10.1 46 9 22 61819 10.2 11 7.5 0192.5 9.0 0.7 0.111.1 15000 800 12106/01 10831 10.0 37 9 22 61819 10.6 11 8 0.2191.8 TR TR 11.0 0.7 0.111.1 15000 800 12107/01 1394/ 10.2 37 11 16 5/7/8 10.4 21 11 1/88 1.5 TR 10.0 0.5 0.111.1 15000 800 4 12/08/01 1850/1787 10.2 43 11 26 2/32/40 10.5 3/ 12 2/86 1.0 TR 9.0 1.2 .05/2.0 15000 1000 3 12109/01 1850/1787 10.0 58 9 38 25/26/26 8.6 1/ 7 0/93 0 0 11.0 1.3 0.5/3.5 13000 1000 0 12/10/01 210012070 10.1 45 9 24 9/13/14 8.5 1 9 2/89 0 7.5 8.5 0.4 0.211.0 14000 1200 0 12/11/01 3035/2770 10.05 46 10 29 11/15/17 9.5 1 11 2/87 .75 10 9 0.7 0.2/1.2 42000 1400 3.1 12/12/01 3600/3279 10.0 50 11 22 12/17/21 9.0 1 11 2/87 1.25 12.3 8.5 0.8 0.2/1.1 37000 1400 4.1 12/13/01 3942/ 10.25 88 14 36 21/33/36 12 2 12 3.5/84.5 1.0 16 9 0.9 0.4/1.2 58000 1600 4.2 12/14/01 4441/3905 10.05 59 14 25 10/19/26 10 1.5 12 3/85 0.75 13 9 0.6 0.3/0.9 54000 1400 3.9 12/15/01 4420/3920 10.1 59 19 27 10/29/24 11 1.5 11 3186 0.75 12 9 0.4 0.3/1.1 47000 1400 3.9 12/16101 5145/4499 10.1 56 14 30 12/26/33 9.5 1.5 11 2.5/86.5 0.50 13 9 0.6 0.4/1.2 60000 1800 4.6 12/17/01 5447/4738 10.1 65 16 26 13123/29 9.0 1.5 12 2/86 0.5 15 9 0.6 0.110.6 57000 1600 4.1 12/18/01 613215257 10.05 56 13 30 12/24/28 9.6 1.25 12 1.25/86.75 0.5 12 8.5 0.1 .0511.2 38500 720 4.5 12/19101 6739 10.15 56 13 37 20/34/38 10.2 2 13 1/86 0.25 13.5 9.2 0.25 0.15/1.8 60000 320 5 12/20/01 7034/5951 10.15 63 14 36 22/36/38 10 2 12 1187 0.5 16 9.2 0.2 0.1/1.7 64500 680 5 12/21/01 7034/5951 10.0 63 12 35 25/37/39 10.2 2 10 .75/89.25 TR 16 9.3 0.2 0.1/1.75 62500 560 - 12/22/01 7034/5951 10.05 61 13 32 22/35/37 9.8 2 12 .75/87.25 0.5 16 9.5 0.25 0.15/2.1 54000 520 5 12/23/01 7089/5994 10.1 55 13 36 17/31/32 10.0 1 11 1.0/88 0.25 13 9.6 0.2 0.1/2.2 64000 680 5 12/24/01 7487/6312 10.05 47 12 31 15/27/28 10.0 2 11 .75/88.25 0.5 12.5 9.6 0.25 0.15/1.8 53500 640 5 12/25/01 7678/6580 10.4 51 13 38 18/30/33 12 2 13 1/86 0.5 13 9.0 0.25 0.1/1.0 53000 600 4 12/26/01 7910/6579 10.45 52 16 37 21/33/36 12 2 13 1.5/85.5 0.4 20 9.0 0.25 0.1/0.7 53000 1200 4.5 12/27/01 7910/6579 10.4 52 14 31 17/29/34 12 1.5 12 1/87 0 14 8.5 0.25 0.6/0.25 47000 1000 4.0 12/28/01 7010/6579 9.35 52 13 26 10/16/23 10 1 11 1.5/87.5 0 12 8.5 0.20 0.1/0.5 51000 800 4.0 12/29/01 7910/6579 10.4 65 15 35 11/19/27 10 1 11 2/87 TR 14 9.0 0.23 0.15/0.9 48000 1000 4.2 [~ EPOCH 65 ( UNOCALe A-15RD ( DEPTHI ASPH- DATE TVD WT VIS PV YP GELS APIFH CK SOL OillWtr SD MBT pH Pm PflMf CI Ca SOL 12/30/01 7910/6579 10.4 66 15 37 16/29/33 10.4 1.5 12 2/86 TR 16 9.0 0.25 0.15/0.9 46000 1000 -- 12/31/01 7910/6579 10.4 65 14 32 11/21/27 10.5 1.5 11 1.5/87.5 0.6 13 9.0 0.25 0.1/0.7 51000 1000 -- 01101/02 8218/6841 10.4 53 15 33 19/32/33 11.8 2 11 1/88 0.5 12.5 9.2 0.2 0.1/1.5 49500 1100 5 01/02/02 8465/7078 10.45 52 14 35 22/34/35 10.6 1.5 11.5 1.0/87.5 0.5 13.5 9.4 0.2 0.1/1.8 49000 820 5 01/03/02 8465/7078 10.45 61 14 37 20/32/33 10.2 1 13 1/86 0.5 11.0 8.9 0.1 0.05/1.6 62500 960 5 01/04/02 8465/7078 10.4 67 16 39 20/31/32 9.6 2 13.0 0.75/86.25 0.5 12.0 8.8 0.1 0.05/1.6 54500 900 5 Epoch on Standby for Mud Reports 1/5-1/12: Convert over to Oil Base 1/13 after 95/8" Casing DEPTHI HTHP Emul DATE TVD WT VIS PV yp GELS Fil CK SOL C.SOL OIL WTR Oil I Water Porn CI Salt Lime Stab. 01/13/02 8475/ 9.4 96 18 20 18/28/31 8 9 76 16 83/17 20000 1 01/14/02 8767/ 9.4 93 21 17 13/23/29 6 NC/2 8 9 76 16 83/17 0.9 23000 18.36 1.17 1700 01/15/02 9138/ 9.4 92 20 17 24/31/34 6 NC/2 9 8.08 78 13 86/14 2.0 24000 22.42 2.6 2000 01/16/02 9179/7326 9.4 121 20 18 24/31/34 6.2 /2 9 8.05 78 13 86/14 2.0 24500 22.78 2.6 1980 01/17/02 9179/7326 9.4 121 20 18 24/31/34 6.2 /2 9 8.05 78 13 86/14 2.0 24500 22.78 2.6 1980 01/18/02 10210/8486 9.4 102 24 20 28/33/39 3.6 NC/2 8 6.72 78 14 85/15 1.15 32000 26.35 1.5 1987 01/19/02 10537/8755 9.45 123 24 18 28/37/41 3.0 NC/2 8.5 7.34 77.5 14 85/15 1.3 29500 24.80 1.69 1938 01/20102 10576/8784 9.45 143 24 18 28/39/41 3.0 NC/2 8.5 7.34 77.5 14 85/15 1.25 29500 24.80 1.63 1923 01/21/02 10994/9123 9.4 101 24 17 26/32/37 5.0 NC/2 8.0 6.72 78 14 85/15 1.15 32000 26.35 1.5 2047 01/22/02 11357/9382 9.4 103 23 18 24/35/36 6.0 NC/2 8.5 8.5 77.5 14 85/15 1.55 32000 25.73 2.02 1900 01/231/02 1151919498 9.45 106 24 18 24/31/36 5.8 NC/2 9.5 8.55 76.5 14 85/15 1.3 30000 25.11 1.69 1765 01/24/02 11756 9.4 103 22 19 24/35/36 5.6 NC/2 8.5 8.5 77 14.5 84/16 1.4 32000 25.67 1.82 1575 01/25/02 12071/9725 9.4 104 24 19 24/35/37 5.2 NC/2 8.0 8.0 77 15 84/16 1.4 34000 26.18 1.82 1854 01/26/02 12335/9805 9.4 104 24 19 23/39/40 5.1 NC/2 8.0 8.0 79 13 86/14 1.4 34000 29.04 1.82 1800 01/27/02 12428/9830 9.4 101 25 17 19/32/34 5.1 NC/2 8.5 8.5 80.5 11 88/12 1.2 35000 33.24 1.56 1780 01/28/02 12428/9830 9.4 119 24 17 20/32/35 5.1 NC/2 8.0 8.0 80 12 87/13 1.3 35000 31.34 1.69 1495 01/29/02 12428/9830 9.45 135 24 21 22/35/37 5.2 NC/2 8.0 6.61 80 12 87/13 1.15 33500 30.4 1.5 1402 01/30/02 12428/9830 9.4 126 25 17 24/34/37 5.2 NC/2 8.0 6.61 80 12 87/13 1.1 33500 30.4 1.43 1426 01/31/02 12428/9830 9.4 144 26 15 24/35/38 5.2 NC/2 8.0 9.61 80 12 87/13 1.1 33500 30.4 1.43 1438 [~ EPOCH 66 ( UNOCALe A-15RD ( DEPTH! HTHP C.SO Oil! Emul DATE TVD WT VIS PV YP GELS Fil CK SOL L OIL WTR Water Porn CI Salt Lime Stab. 021/01/0 1242819830 9.4 134 25 18 24/34/38 5.2 NC/2 8.0 6.61 80 12 87/13 1.05 33500 30.4 1.37 1437 2 BEGIN DATA FOR A15RDST1 02/02/02 12428/9830 9.4 191 25 22 28/36/40 5.4 NC/2 7.0 5.82 79 14 85/15 1.0 30000 25.11 1.3 1539 02/03/02 12426/9830 9.45 223 26 22 29/35/37 4.8 NC/2 8.5 7.45 77.5 14 85/15 1.0 27000 23.18 1.3 1764 02/04/02 10464/8695 9.4 114 22 18 25/34/37 3.8 NC/2 9.0 8.02 77 14 85/15 1.15 25500 22.18 1.5 1469 02/05/02 10859/8900 9.4 100 25 20 23/37/36 4.6 NC/2 8.0 8.0 77 15 84/16 1.5 40000 29.44 1.95 1429 02/06/02 11050/9120 9.4 111 27 19 22135/41 5.0 NC/2 8.0 8.0 77 15 84/16 1.4 38000 28.39 1.82 1550 02/07/02 11205/9200 9.4 123 25 18 24/35/36 4.6 NC/2 9.0 9.0 76 15 84/16 1.25 33000 25.61 1.63 1545 02/08/02 11335/9312 9.4 121 26 19 22/37/40 4.8 NC/2 9.5 9.0 76 15 84/16 1.3 34000 26.18 1.69 1500 02/09/02 11676/9537 9.4 107 24 21 21/37/42 4.4 NC/2 9.0 9.0 77 14 85/15 1.5 34000 27.54 1.95 1550 02/10/02 11853/9590 9.4 115 27 20 24/41/42 4.6 NC/2 8.5 8.5 77.5 14 85/15 1.5 33000 26.95 1.95 1525 02/11/02 12011/9687 9.4 116 27 19 21/36/39 4.6 NC/2 8.0 8.0 78 14 85/15 2.0 33000 26.95 2.6 1610 02/12/02 12271/9759 9.4 108 25 19 24/33/36 4.2 NC/2 9.5 8.39 77.5 13 86/14 1.15 28000 25.21 1.5 1673 02/13/02 12382/9787 9.35 116 25 19 24/34/37 4.0 NC/2 10.0 8.92 77 13 86/14 1.25 27500 24.87 1.63 1731 02/14/02 12382/9787 9.45 141 24 22 25/35/38 4.0 NC/2 9.5 8.39 77.5 13 86/14 1.2 28000 25.21 1.56 1624 02/15/02 12382/9787 9.4 179 23 19 25/34/37 4.4 NC/2 9.0 7.92 78 13 86/14 1.2 27500 24.87 1.56 1648 02/16/02 12380/9786 9.35 162 24 19 24/33/36 4.4 NC/2 9.0 7.92 78 13 86/14 1.2 27500 24.87 1.56 1754 02/17/02 12380/9786 9.4 208 24 21 26/36/40 4.0 NC/2 9.0 7.82 77 14 85/15 1.25 30000 25.11 1.63 1689 02/18/02 12380/9786 9.4 208 24 21 26/36/40 4.0 NC/2 9.0 7.82 77 14 85/15 1.25 30000 25.11 1.63 1689 02/19/02 12375/9807 9.0 141 24 18 19/36/38 3.8 NC/2 7.5 7.5 80.5 12 87/13 1.5 32000 29.44 1.95 1625 02/20/02 12622/9800 9.0 136 23 20 18/36/39 5.1 NC/2 8.0 8.0 80 12 87/13 1.2 31000 28.79 1.56 1971 02/21/02 12796/9793 9.0 138 24 17 21/34/40 4.6 NC/2 8.0 8.0 80 12 87/13 1.3 31000 28.79 1.69 1776 02/22/02 13055/9795 9.0 162 24 18 21/38/43 4.8 NC/2 7.5 8.0 80.5 12 87/13 1.5 31000 28.79 1.95 1850 02/23/02 13159/9769 9.0 136 25 18 19/37/41 4.6 NC/2 9.0 9.0 79 12 87/13 1.3 29000 27.44 1.69 1850 02/24/02 13355/9765 9.0 154 24 17 19/34/37 4.6 NC/2 8.0 8.0 80.5 11.5 88/12 1.2 28000 27.59 1.56 1880 02/25/02 13355/9765 9.1 159 23 17 20/37/44 4.6 NC/2 8.0 8.0 81 11 88/12 1.4 29000 29.21 1.82 1778 02/26/02 13515/9759 9.05 118 23 16 23/34/33 3.6 NC/2 8.0 7.11 80 12 87/13 1.3 23000 23.07 1.69 1973 02/27/02 13620/9781 9.0 110 22 16 21/39/42 3.8 NC/2 8.0 6.97 80 12 87/13 1.2 26000 25.32 1.56 1972 02/28/02 13620/9781 9.0 148 30 19 18/38/40 3.8 NC/2 8.0 6.97 80 12 87/13 1.15 26000 25.32 1.5 1943 BEGIN DATA FOR A 15RDST1 L 1 [~ EPOCH 67 ( 03/01/02 12740/9797 9.0 119 24 18 28/31/39 3.6 NC/2 8.0 6.97 80 12 87/13 1.3 26000 25.32 1.69 1976 03/02/02 13063/9805 8.95 139 24 . 21 27/34/42 4.4 NC/2 8.0 6.77 78 14 85/15 1.2 31000 25.73 1.56 1989 03/03/02 13063/9805 8.95 175 25 18 27/34/42 4.4 NC/2 8.0 6.79 78 14 85/15 1.2 30500 25.43 1.56 1988 03/04/02 13281/9799 9.1 170 28 18 26/34/39 3.8 NC/2 8.0 6.75 78 14 85/15 1.2 31500 26.04 1.56 1946 03/05/02 13369/9795 9.1 169 28 19 20f37/45 4.6 NC/2 8.0 8.0 79 13 86/14 1.0 34000 29.04 1.30 1990 03/06/02 13505/9784 9.0 141 27 17 19/37/42 5.2 NC/2 8.0 7.98 78 14 86/14 1.2 32000 27.81 1.56 1995 03/07f02 13370/9779 9.0 151 27 16 20f38f47 6.8 NC/2.5 8.0 8.0 80 12 87/13 1.4 31000 28.79 1.82 2050 03/08/02 13730/9779 9.0 137 25 17 18/36/42 6.4 NC/2 8.0 8.0 80 12 87/13 1.4 31000 28.79 1.82 2050 03/09/02 13626/9771 9.0 134 27 18 20/37/45 8.8 NC/1.5 8.0 8.0 81 11 88/12 1.8 31000 30.61 2.34 2000 03/10/02 13660/9782 9.0 186 24 16 18/36/40 5.6 NC/2 8.0 8.0 80 12 87/13 1.8 30000 28.12 2.34 2050 03/11/02 13685/9781 9.1 181 23 16 19/36/42 4.4 NC/2 8.0 8.0 80 12 87/13 1.6 31000 28.79 2.08 1969 03/12/02 13992/9777 9.0 144 28 17 21/36/37 5.2 NC/2 8.0 6.86 81 11 88/12 1.3 28000 28.49 1.69 2047 03/13/02 14026/9777 9.1 152 28 17 22/37/38 5.0 NC/2 8.0 6.84 81 11 88/12 1.25 28500 28.85 1.63 2008 03/14/02 14221/9790 9.0 128 26 18 23/33/34 4.8 NC/2 8.0 4.93 78 16 83/17 1.1 28000 21.50 1.43 1832 03/15/02 13992/9777 9.0 144 28 17 21/36/37 5.2 NC/2 8.0 6.86 81 11 88/12 1.3 28000 28.49 1.69 20471 33/16/02 14526/9798 9.0 142 28 16 26/35/38 3.8 NC/2 9.0 7.99 77.5 13.5 85/15 1.15 26000 23.16 1.5 1978 33/17/02 14526/9798 9.0 225 26 20 27/37/42 6.8 NC/2 8.5 7.51 76.5 15 84/16 1.2 26000 21.34 1.56 1340 03/18/02 14838/9805 9.0 138 27 19 27/37/42 4.2 NC/2 8.5 7.47 76.5 15 84/16 1.15 27000 21.98 1.5 2014 33/19/02 14891/9805 9.05 169 28 17 23/39/43 4.8 NC/2 9.0 9.0 77.0 14 85/15 1.6 31000 25.73 2.08 1675 UNOCALe A-15RD ( ~ EPOCH 68 UNOCAL8 A-15RD BIT RECORD BIT SERIAL SIZE JETS DEPTH DEPTH FEET HOURS HOURS HOURS AVG AVG # # INCHES MAKE TYPE (in 32nds) IN OUT TOTAL TOTAL ON BTM OFF BTM FT/HR WOB 1 MJ5916 12.25 SMITH FGSH+C 3X15,1X12 811' 3594' 2783 162.71 48.21 114.50 57.7 20-35 2 7000033 12.25 HUGHES HC607 (PDC) 7X12 3594' 4420' 826 57.37 35.27 22.10 23.4 2-10 3 LR2398 12.25 SMITH M05S0DGC 3X16,1X12 4420' 5451' 1031 50.72 24.18 26.54 42.6 20-35 4 R80DX 12.25 SMITH MX-09DX 3X16,1X14 5451 7034 1683 86.18 40.18 46.00 39.4 20-35 RR3 LR2398 12.25 SMITH M05S0DGC 3X16,1X12 7034 7034 0 29.8 0 29.8 NA NA 5 LR2399 12.25 SMITH M05S0DGE 3X16,1X14 7033 7910 877 96.97 37.70 59.27 23.3 30-40 6 S82DR 12.25 HUGHES MX-09D 3X16, 1X14 7910 8464 554 131.33 17.74 113.59 31.2 30 HO 46254 12.25 SMITH Hole opener 3x20, 1x24 8464 8464 7 100673 8.5 HYCALOG DS75HGJNW 4X10,4X11 8464 9158 694 85.40 27.07 58.37 25.6 2-12 8 X97DP 8.5 HUGHES MX-R20DX2DTI 3x16 9158 10537 1379 80.08 48.53 31.55 28.4 22-30 9 X96DP 8.5 HUGHES MX-R20DX2DTI 3x16 10537 11519 982 90.33 48.47 41.86 20.3 20-28 10 X99DP 8.5 HUGHES MX-R20HDX2 3x16 11519 12428 909 112.42 59.78 52.64 15.2 20-30 11 X94DP 8.5 HUGHES MX-R20CDX2 3x16 12428 12428 0 24.50 0 24.50 NA NA 12 XOODR 8.5 HUGHES MX-R20CDX2 3x16 12428 12428 0 38.52 0 38.52 NA NA BEGIN DATA FOR A15RDST1 1 5013157 8.5 SECURITY FM2843 2X14,1X16 10189 11206 1017 104.07 53.86 50.21 18.9 20-30 2 ER6083PD 8.5 SMITH MJ4654 3x16 11206 11853 647 68.50 44.61 23.89 14.5 20-30 3 MX-R20DX2DTI 8.5 HUGHES 6003504 3x16 11853 12382 529 68.25 40.49 27.76 13.1 20-30 4 XR20HDTGPD 6 SMITH MK1289 3x12 12382 12415 33 35.31 7.50 27.81 4.4 22-30 5 XR20HDTGPD 6 SMITH MK1298 3x12 12415 12468 53 23.7 7.91 15.79 6.7 22-30 6 STX-DS30DX 6 HUGHES P43JR 3x12 12468 12624 156 34.00 19.03 14.97 8.2 20-28 7 EP4970 6 HUGHES D37JN 3x12 12624 13055 431 43.66 25.40 18.26 17.0 20-30 8 XR20HDTGPD 6 SMITH MK1290 3x12 13055 13355 300 47.30 19.51 27.79 15.4 20-30 9 XR20HDTGPD 6 SMITH MK1293 3x12 13355 13620 265 83.40 27.42 55.98 9.7 20-30 BEGIN DATA FOR A15RDST1L 1 10 STX-20D 6 Hughes Hughes 3x12 12700 13063 363 74.75 30.71 44.04 11.8 20-30 11 XR20HDTGPD 6 SMITH MK1297 3x12 13063 13369 306 48.00 19.06 28.94 16.05 20-30 12 XR20HDTGPD 6 SMITH MK1296 3x12 13369 13730 361 52.55 26.02 26.53 13.98 20-30 13 STX-20HDX2 6 HUGHES 5007737 3x12 13406 13660 254 56.50 25.68 30.82 9.89 20-30 BULL NOSE 33/16 UNOCAL BN1 1x23 NA NA NA 24.00 0.00 24.00 NA N/a ( ( [~ EPlJCH 69 ( (, UNOCAL8 A-15RD 14 XR20HDTGPD 6 SMITH MK1294 3x12 13660 14021 361 49.56 25.00 19.56 26.44 20-30 15 XR20HDTGPD 6 SMITH MK1292 3x12 14021 14269 248 21.22 21.28 3.93 11.43 20-30 16 STX-20DX2 6 HUGHES ZM64JG 3x12 14269 14588 289 30.19 22.50 7.69 12.84 22-27 17 STX20DX2 6 HUGHES M6SJG 3x12 14558 14838 280 30.09 22.54 7.55 12.42 20-25 18 XR20HTDGPD 6 SMITH MK1142 3X12 14838 15042 204 15.58 13.80 1.78 14.78 15-20 [:I EPQCH 70 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 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,042 N/A Casing Collapse Structural Conductor Surface 1,540psi Production 4,760psi Liner 7,020psi Liner 6,350psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 93B Trading Bay Hemlock Oil, Undefined Oil Same 9,797 6,100 5,234 2545 6,100 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,780psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 202-019 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20105-02-00 Hilcorp Alaska, LLC Trading Bay ST TBU A-15RD2 Length Size Proposed Pools: L-80 & IBT TVD Burst 4,083 & 12,203 8,160psi MD 6,870psi 3,090psi1,054 6,848 1,07313-3/8" 9-5/8"8,157 1,073 8,157 4,140 - 5,100 4,370 4-1/2" 3,705 - 4,460 9,7867" Other: Install ESP 2/20/2025 14,9392,742 3-1/2" & 4-1/2" 9,805 See schematic See schematic 12,380 Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-062 By Gavin Gluyas at 11:35 am, Feb 07, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.02.07 10:11:45 - 09'00' Dan Marlowe (1267) X DSR-2/18/25SFD 2/11/2025 10-404 BOP test to 3000 psi. Annular test to 2500 psi. See modified procedure email from Eric Dickerson 2/25/25 attached for pressure testing scab liner. Perform No-Flow-Test within 5 days of returning well to production. Provide 48 hrs notice for AOGCC opportunity to witness. BJM 2/25/25 *&: 2/25/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.25 15:29:04 -09'00' RBDMS JSB 022625 Recomplete to Hemlock Well: TBU A-15RD2 Well Name:Trading Bay State A-15RD2 API Number:50-733-20105-02-00 Current Status:Offline ESP Oil Producer Leg:Monopod Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:202-019 First Call Engineer:Eric Dickerman (907) 564-4061 Second Call Engineer:Casey Morse (907) 777-8322 Max. Expected BHP (Hemlock):3,514 psi at 9,692’ tvd (7.0 ppg EMW) – From K-06RD2 BHP data 7/8/2023 Max. Expected BHP (Kenai sands):1,139 psi at 3,705’ tvd (6.0 ppg EMW) – from A-15RD2 fluid level shot 9/1/2024 Max. Potential Surface Pressure:2,545 psi – (Hemlock BHP with 0.1 psi/ft gas gradient to surface) Field/Pool:McArthur River, Trading Bay Undefined Oil Pool. Current Production Interval:Middle Kenai sands, 4,140’ – 5,100’ md Proposed Production Interval:Hemlock, 12,410’ – 14,939’ md Brief Well Summary Monopod A-15RD was drilled Feb 2002 targeting the Hemlock formation in the North Trading Bay Unit. The A- 15RD2 sidetrack deepened the well and added two laterals L1 and L2. The well was converted from gas lift to an ESP in 2014 and a 4-1/2” scab liner was installed across holes in the 7” liner. The ESP failed in 2015, and the supporting injector A-29RD went Not Operable due to TxIA communication. Due to the failed ESP and lack of injection, A-15RD2 was recompleted uphole to the Middle Kenai A sands. Since that time the Hemlock has had minimal offtake in the area and reservoir pressure has declined only slightly possibly indicating aquifer influx. The well is currently a marginal producer at 10 bopd. This in conjunction with adequate reservoir pressure without waterflood injection leads to this project to re-access Hemlock production. Objective: Recomplete the well from a gas lifted Kenai Sands producer to a Hemlock ESP producer. Install a scab liner to shut off Kenai Sands. Recomplete to Hemlock Well: TBU A-15RD2 Notes on wellbore condition: - Last casing test: Tubing by 9-5/8” annulus tested to 1,550 psi after setting production packer at 4,054’. May 11, 2015. - No Flow Test: The well would pass No Flow tests when previously completed as a Hemlock ESP producer. Therefore, a production packer and subsurface safety valve are not planned to be installed. -History: o A-15 abandoned Nov – Dec 2001. o A-15RD abandoned Feb 2002. o A-15RD2 completed with L1 and L2 laterals Mar 2002. o Passing No-flow test November 27, 2013. o RWO to convert from gas lift to ESP - Feb 2014. Production liner cleaned out to 14,960’. 4-1/2” scab liner installed over 7” liner where caliper showed 7” damage. 3% KCl working fluid. 3,475 bbl total fluid loss to well. Pressure tested wellbore above 4-1/2” liner top packer to 1,500psi. o Lost injection support April 2015. o RWO to pull ESP, plug back Hemlock, uphole recomplete to Kenai Sands – May 2015. Fished parted tubing and ESP. Hemlock isolated with 9-5/8” CIBP at 6,100’. The 9-5/8” passed 1,500psi pressure test May 7, 2015. FIW working fluid. 1,789 bbl total fluid loss to well before Hemlock isolated. 9-5/8” passed casing test to 1,550 psi after installing gas lift completion May 11, 2015. Last casing test May 11, 2015 Recomplete to Hemlock Well: TBU A-15RD2 RWO Procedure: 1. Skid Monopod Rig 56 in to position over A-15RD2. 2. Circulate well to KWF: a. Work over fluid will be Filtered Inlet Water (8.4 ppg). b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading. c. Total WBV (initial kill) = 435 bbl i. Tubing volume to 3-1/2” tail = 36 bbl ii. 9-5/8” x 3-1/2” to packer = 249 bbl iii. 9-5/8” volume to CIBP at 6,100’ = 150 bbl d. Total WBV (open to Hemlock) = 727 bbl i. 9-5/8” to 8,010’ = 587 bbl ii. 7” from 8,010’ – 9,547’ = 58 bbl iii. 4-1/2” from 9,547’ – 14,939’ = 82 bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached). a. Notify AOGCC 48 hours in advance for witness. b. Test to 250 psi Low / 3,000 psi High / 2,500 psi Annular. c. BOPE will be used as needed to circulate the well. 4. Pull BPV/TWC. 5. Pull hanger to the floor, then lay down 3-1/2” Gas Lifted completion. RU eline for tubing punch and cut as needed. 6. PU work string. 7. Recover 9-5/8” production packer at 4,054’. Utilize BOPE as necessary to circulate any gas present behind the tubing tail. 8. Recover CIBP at 6,100’. Utilize BOPE as necessary to circulate any gas present below CIBP. 9. Dress off 7” liner top. 10. RIH with 7” scab liner as follows: a. Seal assembly – stung in to top of 7” liner at 8,010’. b. 7”, 26#, L-80 scab liner. c. 9-5/8” x 7” liner top packer assembly. 11. Set 7”scab liner isolating the existing Kenai Sands perforations at 4,140’ – 5,100’. Estimated top of new scab liner is ± 4,000’. 12. Pressure test on top of liner top packer to 1,500 psi for 30 charted minutes. 13. Drift / cleanout the 7” liner interval down to the 4-1/2” liner top at 9,547’. 14. Drift / cleanout the 4-1/2” production interval down to target depth of ± 14,960’. 15. Lay down or rack back workstring. 16. Run new ESP completion with gas lift mandrels. Estimated end of completion ± 9,450’. a. No packer or SSSV are planned due to previous no flow test results. 17. Set BPV/TWC, ND BOP. 18. NU tree and test, pull BPV/TWC. 19. RDMO RWO crew and equipment. Operations: 20. Schedule and perform SVS and No-Flow Test. Provide 48 hours notice to AOGGC for witness. See email from Eric Dickerson 2/25/25 for modified scab liner procedure, including setting RBP at 8150' md and pressure test of 7" seal stem to 1500 psi. -bjm Recomplete to Hemlock Well: TBU A-15RD2 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing 6. Fluid flow diagram 7. RWO Sundry Change Form Monopod Platform Well # A-15RD2 Completed: 05/12/2015 Revised by: JLL 07/21/15 SCHEMATIC CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 13-3/8” 61 K-55 BTC Surf 1073’ 9-5/8” 47 L-80 BTC Surf 8157’ 7” 29 L-80 KC buttress 8010’ 12380’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 12,197' 13198’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 13198’ 13329’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 13329’ 14235’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 14235’ 14939’ 2-7/8” bull nosed hole finder joint on bottom of liner @ 15010’ TUBING DETAIL 3-1/2” 9.2 L-80 SuperMax Surf 4,083’ 4-1/2” 12.6 IBT Scab Liner 9,547’ 12,203’ NO . Depth (MD) Dept h (TVD) ID Item 1 312’ 312’ BOT TE-5 SSSV w/2.812 BX Profile 2 2,112’ 2,077’ GLM 3 2,821’ 2,681’ GLM 4 4,028’ 3,618’ Chem Injection Mandrel 5 4,054’ 3,638’ 9-5/8” 36-53.50# Hydraulic Isolation Packer 6 4,072’ 3,652’ X Nipple – 2.81” Profile 7 4,083’ 3,661’ WLEG 8 6,100’ 5,234’ CIBP 9 9,547’ 7,950’ Baker S-3 Pkr – 5” pin x 4.5” VAM Top Pin 10 12,197’9,740’ Top of 4-1/2” liner with ZXP Liner Top Packer w/ 4.000” seal bore from 12,226’-12,241’ 11 12,203’9,742’3-1/2” 80-40 Locator Seal Assy TD = 15,042’ MD 10,023’ TVD Slotted Liner at Near-Horizontal in HB-1&2 4-1/2” L-80, 11.6# tbg with 2-1/2” x 1/8” slots, 16 slots/ft 13,198’-13,330’ (MD)/9,771’-9,776; (TVD) and 14,234’-14,939’ (MD)/9,877’-9,887’ (TVD) rest is blank liner RKB to TBG Hanger = 40’ 9-5/8” 7” liner cemented at 12,380’ MD/ 9787’ TVD, 76 deg hole 12-1/4” hole to 8,464’ A-15RD2L2 A-15RD2, 13,620’ MD TD A-15RD2L1 13,730’ MD TDA-15RD2, Start = 12,700’ MD A-15RD2L1, Start = 13,406’ MD 5/03: Perfed liner 12,410’-480’ (MD)/9,793’-9,804’ (TVD) 7 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status AZN 13A 4,140’ 4,300’ 3,705’ 3,828’ 160’ Open AZN 25A 4,654’ 5,100’ 4,104’ 4,460’ 446’ Open Hem 12,410' 12,480' 9,793' 9,804' 70 Isolated Hem 13,198' 13,330' 9,771' 9,766' 132 Isolated Hem 14,234' 14,939' 9,887' 10,005' 705 Isolated 8 10 11 Suspected Hole in 7” csg b/t 10,089’ to 10,099’ 6X 2 1 3 4 5 9 Monopod Platform Well # A-15RD2 Completed: Future Revised by: JLL 02/05/25 PROPOSED CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 13-3/8” 61 K-55 BTC 12.515” 36.9’ 1,073’ 9-5/8” 47 L-80 BTC 8.681” 36.9’ 8,157’ 7” 26 L-80 Mixed 6.276” ±4,000’ ±8,010’ 7” 29 L-80 KC buttress 6.184” 8,010’ 12,380’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 12,197' 13,198’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 13,198’ 13,329’ 4-1/2” 12.6 L-80 Hyd 511 blank liner 3.958” 13,329’ 14,235’ 4-1/2” 11.6 L-80 Hyd 511 slotted liner 3.958” 14,235’ 14,939’ 2-7/8” bull nosed hole finder joint on bottom of liner @ 15,010’ TUBING DETAIL 3-1/2” 9.2 L-80 8rd 2.992” Surface ±9,243’ 4-1/2” 12.6 IBT Scab Liner 3.958” 9,547’ 12,203’ NO.Depth MD Depth TVD ID OD Item 1 TBD GLM’s 2 ±9,243’ ±7,704’ Head Bolt On Discharge Pump Intake Motor ±9,450’ ±7,873’ Gauge/Centralizer/Anode 3 9,547’ 7,950’ Baker S-3 Pkr – 5” pin x 4.5’ VAM Top Pin 4 12,197’ 9,740’Top of 4-1/2” liner with ZXP Liner Top Packer w/ 4.000” seal bore from 12,226’-12.241’ 5 12,203’ 9,742’ 3-1/2” 80-40 Locator Seal Assy TD = 15,042’ MD 10,023’ TVDSlotted Liner at Near-Horizontal in HB-1&2 4-1/2” L-80, 11.6# tbg with 2-1/2” x 1/8” slots, 16 slots/ft 13,198’-13,330’ (MD)/9,771’-9,776; (TVD) and 14,234’-14,939’ (MD)/9,877’-9,887’ (TVD) rest is blank liner RKB to TBG Hanger = 40’ 1 2 9-5/8” at 8,157’ MD 7” liner cemented at 12,380’ MD/ 9787’ TVD, 76 deg hole angle 12-1/4” hole to 8,464’ A-15RD2L2 A-15RD2, 13,620’ MD TD A-15RD2L1 13,730’ MD TDA-15RD2, Start = 12,700’ MD A-15RD2L1, Start = 13,406’ MD 5/03: Perfed liner 12,410’-480’ (MD)/9,793’-9,804’ (TVD) 3 4 5 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Status ANZ 13A 4,140’ 4,300’ 3,705’ 3,828’ 160’Isolated AZN 25A 4,654’ 5,100’ 4,104’ 4,460’ 446’Isolated Hem 12,410' 12,480' 9,793' 9,804' 70 Open Hem 13,198' 13,330' 9,771' 9,766' 132 Open Hem 14,234' 14,939' 9,887' 10,005' 705 Open Monopod Platform A-15RD2 Current 01/27/2025 13 3/8'’ 9 5/8'’ 3 ½’’ Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2'’ LPO No slips or packoff in head, removed during 2002 redrill Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Casing spool, OCT-C22-BG, 13 5/8 3M X 13 5/8 3M, w/ 2- 2'’ LPO 9 5/8 casing hung off in this spool, C-22 slips Valve, CIW-F, 2'’ LPO 3M, HWO, AA Tubing hanger, CIW-DCB-FBB, 11 X 3 ½ EUE lift and 3 ½ EUE susp, w/ 3'’ type H BPV profile, 2- ¼’’ continuous control lines Valve, Swab, WKM-M, 3 1/8 5M FE, HWO, DD trim BHTA, Bowen, 3 1/8 5M X 3.5 Bowen top Adapter, CIW-FBB,11'’ 5M FE X 3 1/8 5M stdd top, w/ ½ npt control line exits, 6 1/4'’ seal pocket Monopod A-15RD2 13 3/8 X 9 5/8 X 3 ½ Valve, Master, WKM-M, 3 1/8 5M FE, HWO, DD trim Monopod Platform A-15RD2 Proposed 01/27/2025 BHTA, Bowen, 4 1/16 5M FE x 7'’ quick union top Valve, Upper master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, EE trim Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator 13 3/8'’ 9 5/8'’ 4 ½’’ Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2'’ LPO No slips or packoff in head, removed during 2002 redrill Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Casing spool, OCT-C22-BG, 13 5/8 3M X 13 5/8 3M, w/ 2- 2'’ LPO 9 5/8 casing hung off in this spool, C-22 slips Valve, CIW-F, 2'’ LPO 3M, HWO, AA Tubing hanger, CIW-DCB-FBB-ESP, 11 X 4 ½ IBT lift and susp, w/4'’ type H BPV profile, 4- ¼’’ continuous control lines Monopod A-15RD2 13 3/8 X 9 5/8 X 4 ½ X4 control line Monopod Platform 2025 BOP Stack (Workover) 02/06/2025 13 5/8 5M Shaffer Riser 13 5/8 5M FE X 13 5/8 5M FE Shaffer SL Shaffer SL 13 5/8 5M 13 5/8 5M Drill deck 1.76' 1.44' 14.20' 14.20' 3.74' 2.83' Rig Floor 16'’ Pipe 26.25' Bottom of air boot flange 5' below rig floor 7'’ rams 2 7/8-5.5 Variables Blind 1.00'Spacer spool 13 5/8 5M FE X 11 5M Hilcorp Monopod Rig 56 Flow Diagram LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve MUD PUMP 4.30' PIT SYSTEM CHOKE MANIFOLD Choke Line Panic Line C12 C13 C15 C14 C16 AB C4 C5 C6 C7C2 C10 C9 C11 C8 C3 P HCR1 Open ClosedClosedOpen Open Open OpenAnnular VBR BLIND SucƟon MUD PUMP SHAKERSHAKERKill Line Trip Tank P P C1 C GAS BUSTER HCR2 4” Demco kill line Flow line P P Hilcorp Monopod Rig 56 Flow Diagram Reverse Circulating 4” Demco kill line LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve MUD PUMP 4.30' PIT SYSTEM CHOKE MANIFOLD Choke Line Panic Line C12 C13 C15 C14 C16 AB C4 C5 C6 C7C2 C10 C9 C11 C8 C3 P HCR1 Open ClosedOpenOpen Open Open ClosedAnnular VBR BLIND SucƟon MUD PUMP SHAKERSHAKERKill Line Trip Tank P P C1 C GAS BUSTER HCR2 Flow line P P 4 11 C To Gas Buster White Normally Open 3-6-7-15 Black Normally Closed 1-2-4-5-8-9-10 11-12-13-14-16 From BOP 1413 10 12 3 2 8 1 B 5 6 7 A 9 16 15 D To Panic Line To Sending Unit Monopod Rig 51 Choke Manifold Item 3 & 5 4, 13, 15, 16 1-2, 6-12, 14 A B-C D ĞƐĐƌŝƉƟŽŶ 3 1/8 5M Vetco 2200T Gate Valve 4 1/16 5M Cameron Gate Valve 3 1/8 5M Cameron Gate Valve Swaco 2 9/16 10M Super Choke 3 1/8 5M Cameron H2 Manual Choke 3 1/8 5M Cameron H2 PosiƟve Choke Install 4 1/16 5M API instrument Ňange below panic line w/ ½ npt drain ports Monpopod Valve Alignment –Long Way Valve PosiƟon (O- Open/ C- Closed Monpopod Valve Alignment –Reverse Valve PosiƟon (O- Open/ C-Closed Annular O Annular C VBR O VBR O Blind O Blind O C1 C C1 C C2 C C2 C C3 O C3 O C4 C C4 C C5 C C5 C C6 O C6 O C7 O C7 O C8 C C8 C C9 C C9 C C10 C C10 C C11 C C11 C C12 C C12 C C13 C C13 C C14 C C14 C C15 O C15 O C16 C C16 C HCR1 C HCR1 C Wing1 (W1) O Wing1 (W1) O HCR2 C HCR2 C Wing2 (W2) O Wing2 (W2) O Demco4”KillLine C Demco4”KillLine O Stand Pipe Valve (SP1) O Stand Pipe Valve (SP1) C Cement Line (CL1) C Cement Line (CL1) C Trip Tank 1 (TT1) C Trip Tank 1 (TT1) C Reverse Line (RV1) C Reverse Line (RV1) O Mud Pump 1 (MP1) O Mud Pump 1 (MP1) O Mud Pump 2 (MP2) O Mud Pump 2 (MP2) O Mud Pump 3 (MP3) O Mud Pump 3 (MP3) O Mud Pump 4 (MP4) O Mud Pump 4 (MP4) O Pit Outlet 1 (PO1) O Pit Outlet 1 (PO1) O Pit Outlet 2 (PO2) C Pit Outlet 2 (PO2) C Pit Outlet 3(PO3) C Pit Outlet 3(PO3) C MP3 SP1 PO3PO2 MP4 MP1MP2 MP3MP4MP1MP2 W2 W1 W2 CEMENT LINE W1 TT1 TT1 RV1 RV1 CL1 PO1 PO3PO2PO1 7" Ram 7" Ram Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well: Trading Bay St A-15RD2 (PTD 202-019) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 1 McLellan, Bryan J (OGC) From:Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent:Tuesday, February 25, 2025 11:57 AM To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] TBU A-15RD2 (PTD 202-019) RWO sundry Bryan, My proposal to test the seals would be the steps below (addiƟons in red). Please let me know if this is acceptable. 9. Dress off 7” liner top. 10. Set 7” retrievable bridge plug at ± 8,150’ (below the current 7” liner top). 11. RIH with 7” scab liner as follows: a. Seal assembly – stung in to top of 7” liner at 8,010’. b. 7”, 26#, L-80 scab liner. c. 9-5/8” x 7” liner top packer assembly. 12. Sting seal assembly in to 7” tie back sleeve. Pressure test the seal assembly to 1,500 psi for 30 charted minutes. 13. Set 7”scab liner isolating the existing Kenai Sands perforations at 4,140’ – 5,100’. Estimated top of new scab liner is ± 4,100’. 14. Pressure test on top of liner top packer to 1,500 psi for 30 charted minutes. 15. Pull the 7” retrievable bride plug. 16. Drift / cleanout the 7” liner interval down to the 4-1/2” liner top at 9,547’. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, February 25, 2025 10:23 AM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] TBU A-15RD2 (PTD 202-019) RWO sundry As a follow up, here’s a snip indicating which seals need to be tested, circled in blue pen. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders . 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Tuesday, February 25, 2025 10:22 AM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] TBU A-15RD2 (PTD 202-019) RWO sundry Eric, On question #2 below, it appears that you won’t be testing where the 7” scab liner stabs into the existing 7” liner top at 8010’ md, so you don’t know if the perfs from 4140-5100’ are isolated. Need a plan to prove they are isolated. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 3 From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Friday, February 21, 2025 11:28 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] TBU A-15RD2 (PTD 202-019) RWO sundry Bryan, x For both the CIBP and packer, the recovery plan is to burnover the slip segments, then spear the body ID. The CIBP may require an addiƟonal junk basket run if the nose cone is not recovered with the spear. x AŌer running the 7” scab liner the 7” liner top packer and the 9-5/8” casing will be tested by pressuring up on the backside of the workstring. x Good idea on the 7” scab liner top, I will shoot to be closer to the top perf. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, February 17, 2025 4:57 PM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Subject: [EXTERNAL] TBU A-15RD2 (PTD 202-019) RWO sundry Eric, A few questions about the sundry application: 1. How will you recover the packer and CIBP? 2. What portion of the well will be pressure tested after running the 7” scab liner? Are you setting a plug in the 4-1/2” liner top? 3. Consider setting the 7” scab liner top packer a bit deeper so you would eventually be able to P&A the well per regulation 20 AAC 25.112(c)(1)(E). Not required at this time, but maybe set yourself up for future success. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov CAUTION: This email originated from outside the State of Alaska mail system. 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