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Home My WebLink About213-010Loepp, Victoria T (DOA) From: lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, May 18, 2015 4:04 PM To: Loepp, Victoria T (DOA); Hunt, Jennifer L (DOA) Subject: Expired Permit to Drill 01-10A (PTD #213-010) Follow Up Flag: Follow up Flag Status: Flagged Hello, Just wanted to clear an expired Permit to Drill for well 01-10A. The sundry has also expired. Please let me know if you have any questions. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 -------------------------------------------------------------------------------------------- : i BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK -------------------------------------------------------------------------------------------- 1 THE STATE Alaska Oil and Gas o' 1Ll 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-1 OA TI TI T_ Dr Exploration (tklaska\), Inc. Permit No: 213 -0 10 Surface Location: 1429' FNL, 1588' FWL, SEC. 08, T10N, R15E, UM Bottomhole Location: 2120' FNL, 1052' FWL, SEC. 08, T10N, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P oerster Chair 5� DATED this �J� day of January, 2013. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALA; OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JAN 0 q 2013 1 a.Type of work: 1 b.Proposed Well Class: ® Development Oil - ❑ Service - Winj ® Single Zone . 1 c. Specify if well is proposed for: ❑ Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Redrill •❑ Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No 6194193 • PBU 01-10A ' 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11520 • TVD 8755'ss Prudhoe Bay / Prudhoe Bay . 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028329 1429' FNL, 1588' FWL, Sec. 08, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3958' FNL, 1126' FWL, Sec. 08, T10N, R15E, UM March 20, 2013 , 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 2120' FNL, 1052' FWL, Sec. 08, T10N, R15E, UM 2560 22000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 72' . feet 15.Distance to Nearest Well Open Surface: x 698940 y- 5939500 • Zone- ASP4 GL Elevation above MSL: 39.5' feet to Same Pool: 1150' 16. Deviated Wells: Kickoff Depth: 9380' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 115 degrees Downhole: 3260 • Surface: 2380 - 18. Casing Program S ecifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 3-1/2" x 3-1/4" 9.3# / 6.2# L-80 STL/TC-II 2570 8950' 8311'ss 11520' 8755'ss 131 sx Class 'G' x 2-7/8" / 6.5# / STL 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured). 9996' 9383 9514' 9514' 8921' 1 Unknown Casing Length Size Cement Volume MD TVD Conductor / Structural 100, 20" 260 sx Arctic Set (Approx.) 100, 100, Surface 2663' 13-3/8" 7000 sx Permaftost II 2663' 2663' Intermediate 9942' 9-5/8" 1200 sx Class 'G125 sx PF II 9942' 9331' Production Liner Perforation Depth MD (ft): 9450' - 9508' Perforation Depth TVD (ft): 8860' - 8915' 20.Attachments: ❑ Property Plat 0 BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ® Diverter Sketch ❑ Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. 1 hereby certify that the foregoing is true and correct: Date Contact Ron Phillips, 564-5913 Printed Name ,John Title Engineering Team Leader Email Ron.Phillips@bp.com Signature - Phone 564-4711 Date li Commission Use Only Permit To Dnll� `2 ��U API Number: Permit Approval Date: See cover letter for Number: / J 50-029-20169-01-00 q other requirements: Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Other: /� 6) 1J fts �v 3 �U D /� S 1 Samples Req'd ❑ Yes 0 No Mud Log Req'd: [I Yes Ej/No /Yes /✓ HZS Measures: [ ❑ No Directional Survey Req'd: ❑ Yes ❑ No Spacing exception req'd: ❑ Yes EfNo inclination -only svy Req'd: ❑ Yes ❑/No APPROVED BY APPROVED B4 OMMISSIONER THE COMMISSION Date —3 — Form �O hRevjsed 10/ 1 -� MALT permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit o d t c t m u r` VV �11�i4i /S� , .1�,2 ��1l� �a To: Alaska Oil & Gas Conservation Commission From: Ron Phillips (D by CTD Engineer Date: January 4, 2013 Re: 01-10A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 01-10 with SLB/Nordic 1 Coiled Tubing drilling rig targeting the Ivishak Z4, Z3 and Z2 sands in the central DS-01 area. CTD Drill and Complete 01-10A program: Rig Start Date: March 20, 2013 Pre -Rig Work: (scheduled to begin January 18, 2013) 1. F MIT- IA to 3,000 psi, MIT-OA to 2,000 psi). 2. W Cycle LDS; PPPOT- T to 5,000 psi. 3. S Pull tubing patches from 4,730' and 4,808'. Pull nipple reducer from 8,890'. 4. C Mill XN nipple at 8,963' to 3.80". 5. C Set 50 bbl, 17 ppg cement plug in the 9-5/8" casing. Clean out down to 8,960'. 6. S Drift tubing down to 8,960' with 3.7" x 15' dummy whipstock. 7. V PT MV, SV, WV. 8. F CMIT-IAxT to 2,500 psi. (Wait 24 hours for cement plug to set.) Bleed wellhead pressures down to zero. 9. O Bleed production flow lines and gas lines down to zero and blind flange. 10. O Remove wellhouse, level pad. p ,D To -/ � --- o 43 Rig Work: (scheduled to begin on March 20, 2013) _S-&l e 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. /'fit) fy IrL7 5 4oh e'er 2. Drill 3.80" pilot hole from top o cementat own to 9,430' ( 0' Rat hole). 3. Calliper Pilot hole using PDC logging conveyed on coil. 4. Run 3.7"x 15' dummy whipstock drift. Set 3-5/8" OH anchor whipstock at 9,380' (Top of Whipstock)., 5. Mill 3.80" window at 9,380' and 10' of rathole. 6. Drill Build: 4-1/4" OH, 320' (30 deg/100 planned). 7. Drill Lateral: 4-1/4" OH, 1,800' (12 deg/100 planned) with resistivity. 8. Run Triple Combo Open Hole Logs. 9. Run 3-1/4" XO 2-7/8" L-80 liner leaving TOL at 8,950' MD. 10. Pump primary cement leaving TOC at TOL at 8,950' MD, 27 bbls of 15.8 ppg liner cmt planned. 11. Make a liner cleanout run combined with MCNL/GR/CCL logging run. NV 12. Test liner lap to 2,400 psi. �DT-4 13. Perforate liner per asset instructions (-100'). 14. Freeze protect well, set BPV, RDMO. ! 3 -° 1 `� Post -Rig Work: 1)f3U 61-la4 1. Set 4-'/2" liner top packer, and test to 2,400 psi (if fails liner lap test). 2. Re -install wellhouse and FL's. 3. Generic GLV's. Mud Program: • Milling/drilling: 8.6 ppg Geo Vis for milling window and drilling ( 677 psi over -balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/4" Liner Program: • 3-1/2", 9.3#, L-80, STL Solid Liner 8,950' MD — 8,980' MD • 3-1/4", 6.2#, L-80, TC-II Solid Liner 8,980' MD — 9820' MD • 2-7/8", 6.5#, L-80, STL Solid Liner 9,820' MD — 11,520' MD • A minimum of 27 bbls of 15.8 ppg cement will be used for liner cementing. (TOC at TOL at 8,950' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg. ' • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 1150. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line — 22,000'. • Distance to nearest well within pool — 1,150'. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section • Triple Combo Open Hole Logging: Gamma Ray, Induction Resistivity, Density, Neutron. • Cased hole GR/CCL/MCNL logs will be run. Perforating: • SWS 2" 2006 PJ HMX, 6 spf, 601 phasing pert guns. • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures • None Hazards • The maximum recorded H2S level on DS 1 was 60 ppm on well 01-34A on 3/6/2011. Reservoir Pressure • The reservoir pressure on 01-10A is expected to be 3,260 psi at 8,800' TVDSS. (7.12 ppg). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,380 psi. • An EMW of 8.4 ppg for this well will provide 586 psi over -balance to the reservoir. Ron Phillips CC: Well File CTD Engineer Sondra Stewman / Joseph Lastufka WaLHEAD= RVIC ACTUATOR = AXE_SON KB. E_EV = 77 BF EEV = KOP= 3000' Max Angle = 31 @ 6238' Datum MD = 94BY DalumTVD= 88W SS 13-3V CSG, 72#, W80, ID=12-347" 1--1 2653' Mininnim ID = 2.313- @ 88W 2 7l8" NIPPLE REDUCER 5-12" TBG, 17#,13CR80, _0232 bpf, ID= 4.892" 6 777 1 4-1/7' _0152bpf,ID=3.955 1-1 8975' PERFORATION SUAANARY Rff LOG MM ON 0911875 ANGLEATTOPFERF 1T4#9495' Note_ Pder to FFoduchm OB for historical pert data SIZE SPF NIFEZVAL OpnlSgz DATE 2-V4" 6 9495 - 9508 0 12/20105 2' 6 9450 - 9460 0 05117/11 2-V8' 2 9514 - 9528 S 0912494 3-318' 6 9528 - 9583 S 11/27105 9584 - 9658 S 09/24194 9-5W CSG, 47#, M+18015OO-95, ID=B_681- 9942' (—TD� 9998' SA" NOTES: mE40 CFME TB6 H.1 & PSE RW- 01 10 R N MW RM HAVERMUC® TEST PRESS M LIMr iS IN SOMECASEIL CONTACT YYIE(x5102) PRIOR TD PiaMS RE TESTING 2085' S-w- CAMOo BAL-O SSSV NP, ID= 4.562' GAS LIFT MA IMIS ST MD TVD DLV -1Y PE V LV LATCH I PORT I DATE 1 3103 5147 6998 8018 3102 5010 6618 7518 6 26 31 24 LB1 LB1 MMG OT1S SO DMY OW DW T-2 T-2 RA RA 20 0 0 0 09105709 3 4 4SW 4M 5-112" HES DWPCR PATCH (oa112109), ID= 2.987" 1 4T30r�75Q 5-117 HES MP CR PATCH (08112109), ID = 2.98Y 60173 5-112" X 4-IP- XO, ID = 3-9 MW-14-112" OTIS X NP, ID = 3.813" 2-718' NP R®11CJ32 (08J09109), ID = 2313' a91Q 9-518" T1W LATCH AssmvLY wIHBBPPKR, ID=4.00" 894V 4-12" OTIS X NP ID = 3.813" 89W 1--14-10-OTISXNMP, ID=3.725- j 89 'V j j4-1r2" WLM, ID= 3-%W >�72' aTTT LOG 08/11/09 9514' ELMDI-IT0P0FCBiFNT(05181511 ®C r.� �•. DATE I REV BY OOLSS34 S DATE I REV BY OO AMENM 09126175 ORIGINAL COMPLEItON 08I09109 GJFITLH NPRED JCER SET 0611110" Im 08/12109 MWT I-11 2 PATCI ES SET 120005 RWLJTLH PERFS(IN20105) 09105f09 GTWIILH GLV 00 0WM08 SWCISV GLV CIO (09►08108) 0429111 DAVIPJC NPREJIJCEt CORRECTION 10M V08 JKDdPJC SET IBP (IOAM081 05121/11 TT W PJC EA+DT0G PERF (5115111) FRUDHOE BAY UNIT WELL 01-10 PERMT No_ "1750430 AR No= 50-029-20169-00 SEC 8, T10N, 1115P 424T FE & 412T FPL WELLHEAD= FKc ACTUATOR = AXELSON KB ELEV = 77 BF ELEV = KOP= 3000' Max Angle = 31 Q 6239 Dahrm ND = 946T DafumTVD= 88W SS 13-3f l- CSG, 72#, MN-80, D=12.347" 1--1 256W Minimum ID = 2313- @ 889W 2 7W NIPPLE REDUCER 5-UY TBG, 17#, 13CR-80, -02V bpf. ID= 4-892- I-� W7W Top of Cement - 8,960' 4-lf-r TBG, 126#;13CR-80, -0152 bpf, ID = 3.955 897T PERFORATION SUMMRY REFLOG BHCS ON 09/18175 ANGLEAT TOP PBRF 17- @ 94W Note= Rafer W Roducbon OB for historical perf data SIZE SPF INTERVAL OpniSW DATE 2-114' 6 9495 - 9508 s pre -rig 2' 6 9450 - 9460 s pre -rig 2-118' 2 9514 - 9528 S 0924194 3-V8' 6 9528 - 9583 S 11/27/05 9584 - 9658 S 0924194 9-5W CSG, 47#, WMS00-95, ID=8.681- 9942' F I U 99W o O SAFETY NOTES: --CHWYETBG & ECLPSEPfQ� F TW 6 MRS HAVEREDUC® TOT PRESSURE LI►.. vS IN SOYECASEL CONTACTWIE(x6102) Pre -Rig POM TO PRESSURE TESTING- 2085' S 12' CAMCO BAL-O SSSV NIP, ID= 4_562- GAS LIFT RAMCRIiS SF ND TV D DEV TYPE V LV LATCH PORT DATE 1 3103 5147 6998 8018 3102 5010 6618 7518 6 26 31 24 LB1 LB1 MUG OTIS SO DW DW DW T-2 T-2 RA RA 20 0 0 0 09105/09 3 4 6073' S-112'X4-12'X0,ID=3.958' 8890' �14-12-OMSXNP,ID=3_813- 8910r 9 5 TIW LATCH ASSH BLY wI HTBP nak ID = 4.00' 04G 4-12'0-MXNP.ID=1817 89" 14-12- OTIS XN NP,11)= 3.80- mied pie-ng { 8919 [ j4-1rr WLE, ID= 3_9W 8972' H BJYDTTL0G08111109 9574• fFLMD T0P0FC61�If(051815111) ???? H FISH - 0M S NP FEDUCER DATE I REV BY COLOAMS DATE I REV BY OOLOMMS 0I1126I75 ORGNAL COMPLETION 08/09109 GJFITLH NPREDUC132 SET Y810M RWO 08/12109 IV/ fMl 2 PATMES SET 12►30105 RWUTIH PBRFS (12M%) 09105109 GTWfrLH GLV 00 091 O8 SW(YSV GLV CIO (09108108) 04rMl l DAVIPJC NPR®UCC.B2 CORR _T 10/11/08 JKUPJC SEf I0P(1OM08) 05/21111 TTR7 PJC I EL DTOCI PERF(5115111) PRUUHC)E BAY UNIT WELL 01-10 PDRMT No_ "1750430 AR No_ 50-029-20169-00 SEE 8, T10N, R15P 424T FEL & 412T FNL FMIC WELLHEAD= FMC ACRIATOR = AXELSON KB ELEV = 77 BF ELEV = KOP= 3000' Max Angle = 31 @ 6238 DafumMD= 946T DahumTVD= 88W SS 01-10A Planned CTD Sidetrack 13-3V CSG, 72#, W 80, ID =12347- 2663' Tubing patches pulled and re -run POST Minimum ID = 2.313" @ 889W 2 7W NIPPLE REDUCER 5-1IL' TBG, 17#, 13CR-80, -0232 bpf, ID= 4.892- 1-1 6077 TOIL —8,950' MD TOP of Cement RampM/S Window —9, 380' M D 1800 ROH 4112" TBG, 1261# 13cwso, _0152 W. D= 3-9Z TS PERFORATIONSUMMARY REF LOG BHCS ON 09MSf75 AN3LEAT TOP PEW 17- @ 90W Noll- ReferbD Rodudm DBfar heJuxal pert dab SVE SW MERVAL OpnISW DATE 2-114' 6 9495 - 95M 0 12rAN05 21 6 9450 - 9460 0 05M7111 2-W 2 9514 - 9528 s 09124194 3-3V 6 9528 - 9583 s 11127105 9584 - 9658 s 0924194 9-5Ar F-TD7-F 99W 170 SAWIT NOTES: --CHRUMEIM a E13 PSEROim Ff W HOW FKRS HAVEIaDUC® TEST PRESSIM LD■..SINSOMECASM 0ONTACTVVIE(X5IO2) PfaOR M PIaRMM TMTNG 2085'—15-12' GMWOD BAL-O SSSV NP, ID= 4.562' GAS LIFT MANDRELS, ST MD TVD DEV TYPE V LV LATCH PORT DATE 1 3103 3102 6 LB1 SO T-2 20 09K&09 5147 5010 26 LB1 DMY T-2 0 3 6998 6618 31 IMAG OW RA 0 4 8018 7518 24 OTIS DMY RA 0 4 w-4a '—�5-1I2' HEs DWPcR PATCH (08112m% ID= 298T 47W.4750r 5-12' HES DWP CR PATCH (08f12109), ID= 298T Nip Reducer retrieved! - 8890' 412' OTIS X NP, D = 3.813' ® 2-7/SNPR®L)L132(OS►09109),D=2313 - 891p 9-5W T1W LATC H ASSH BLY w/ HBBP PKR, ID = 4_00' -F—w—w---1 412' OTIS X NP 1) = 3.817 89W I—j4-1rZ 0fSXNNP D=3- 25 I Mill to 3.80" 8975 412' WL�, D= 3.958' lM72' ELIuDTT LOG 08"Q9 2-7/8" L-80 LinerTD -11,520' MD 9514' ELMO HTOPOFCIMW (05f815f11) Z4 exit 17 deg lowside 3 3M H FISH - OTIS NPREAK;E R (11f8U92) L DATE I REV BY I GonAueKS I DATE j RLV BY I (X*AVI ITS 109128751 1 ORGNALCOMPLEHON 11081091091 GJRTLH I NPRE LICERSET 2 PATCtES SET GLV C70 I OWM08 I SWC7SV IGLV 00 (091D8108) 10429f11 I DAVIPJCINPREDU(ERGA4aA--ON 10/11/08 JK[YPJC SETIBP(101)9f08) 1051211111 TTR/PJC I ELIYDTOCIPERF(5115/11) PRUDI DE BAY UNT WELL 01-10 PBMT Pb--'1750430 AR Nb- 50-029-20169-00 SEC 8. 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INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB IDS 01 Site Error: 0.00ft Reference Well: 01-10 Well Error: 0.00ft Reference Wellbore 01-10A Reference Design: Plan 4 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 01-10 - Slot 10 18 : 10 9/2/1975 00:00 @ 72.00ft (generic drilling rig) 18 : 10 9/2/1975 00:00 @ 72.00ft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM .16 - ANC Prod - WH24P Offset Datum Reference Plan 4 "liter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere nterpolation Method: MD Interval 25.00ft Error Model: ISCWSA )epth Range: 9,187.00 to 11,520.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,348.80ft Error Surface: Elliptical Conic Survey Tool Program Date 1/3/2013 From To (ft) (ft) Survey (Wellbore) Tool Name Description 173.00 9,187.00 1 : Camera based mag multi sho (01-10) CB-MAG-MS Camera based mag multi shot 9,187.00 11,520.00 Plan 4(01-10A) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 9,380.00 8,792.95 9 5/8" 9.625 12.250 11,520.00 8,827.09 2 7/8" 2.875 4.250 Summary Site Name Offset Well - Wellbore - Design PBDS01 01-05 - Plan 01-05B Contingency - 1-05B Cont WI 01-07 - 01-07 - 01-07 01-07 - 01-07A - 01-07A 01-07 - 01-07APB1 - 01-07APB1 01-09 - 01-09 - 01-09 01-09 - 01-09A - 01-09A 01-10-01-10-01-10 01-11 -01-11 -01-11 01-18 - 01-18A - 01-18A 01-30 - 01-30 - 01-30 01-30 - Plan 01-30a - 01-30a wp02 01-34 - 01-34 - 01-34 01-34 - 01-34A - 01-34A Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 9,284.60 15,056.93 355.17 270.40 9,424.75 9,425.00 2.49 9.78 9,187.21 9,900.00 976.41 362.36 11,059.34 9,175.00 1,110.38 390.69 11,075.00 9,075.00 1,106.42 396.85 10,700.00 9,350.00 1,333.95 425.78 10,800.00 9,450.00 1,120.34 346.65 99.62 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range -5.80 FAIL - Major Risk Out of range 660.91 Pass - Major Risk 746.85 Pass - Major Risk 748.20 Pass - Major Risk 911.35 Pass - Major Risk 781.21 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11312013 10:23.01AM Page 2 of 11 COMPASS 2003.16 Build 73 {! i ti...�..: U �5 Ssa g ga'a DES a • n seY z u :S = Q n O Q m m OLL S z Ca C 9 z O 1 J D L) ' C) ' J W ' �W I.L W OT I i U T \J 9 CO J U U s � m � o O z s 0 5 I a LL F Qb g Wa =� a N H = Y O U C U U e r J J u O U t7 U U a' a' $ m > U a f 0 f O w �d a� o. TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through tar et zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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