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211-010
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,742 feet None feet true vertical 7,027 feet None feet Effective Depth measured 15,742 feet 8,700 feet true vertical 7,027 feet 6,926 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3.5" L-80 8753' MD 6,936' TVD Packers and SSSV (type, measured and true vertical depth)8,700' MD 2057' MD 6,926' TVD 1,992' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Alpine Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3.5" Exisiting: 6975-6975, 6992-6992, 6997-6997, 7003-7003, 7014-7014, 7025-7025, 7022-7022, 7009-7009, 7025-7025', 7023-7023', 7014-7015' 2024 New: 6965-6966', 6996-6996', 7019'-7020' 2663 2457 Burst Collapse Liner 8845' 7041' Casing 6953 7027 8870 15742 2635' 114Conductor Surface measured TVD 7" Plugs Junk measured Length measured true vertical Packer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-010 50-103-20635-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 372104, ADL 372105 Alpine Pool CRU CD3-199 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 447 Gas-Mcf MD 1508 Size 114 36 14602761 218 19327 216 Intermediate 16" 9.625" 83' N/A Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 2309 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer:HRD ZXP Liner Top Packer SSSV-Camco TRMAXX-5E Mark Shulman mark.shulman@cop.com (907) 263-3782Sr. Production Engineer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Existing: 9419-9424, 10313-10318, 11303-11308, 12108-12113, 12849-12854, 13904-13909, 14960-14965, 14300-14320', 14850-14870', 15500-15520', 15695-15705 New 2024: 9,000'-9,020-, 11,000'-11,020' and 13,100-13,120' MD Fra O s 6. A PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:56 am, Apr 23, 2024 Mark Shulman Digitally signed by Mark Shulman Date: 2024.04.22 17:19:25 -08'00' Adobe Acrobat Reader version: 2024.001.20643 DSR-4/23/24 RBDMS JSB 043024 CD3-199 Perforations DTTMSTART JOBTYP SUMMARYOPS 3/30/2024 MAINTAIN WELL CONTINUE POOH, RIG DOWN. 3/29/2024 MAINTAIN WELL PULL 3 1/3" WRDP @ 2050' CTMD. RIH W/ MOTOR @ 2.68" AR 5 BLADE JUNK MILL WASHING ACROSS ALL FRAC PORTS DOWN TO TAG @ 15,732' CTMD. RUN 20' PERF GUNS (6 SPF, 2006 PJ OMEGA 60* PHASE, 7.3GM), SHOOT PERF'S FROM 13,100'-13,120', 11,000-11,020, & 9000-9020. CURRENTLY PULLING OOH. 3/28/2024 MAINTAIN WELL RIG UP CTU W/ 18.890' OF 2" CT & SUPPORT EQUIPMENT. PULLED 3 1/2" SLIP STOP @ 2048' CTMD. IN PROGRESS. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD3-199 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled WRDP & APERF, Set ISO Sleeve CD3-199 4/6/2024 oberr Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 31.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 26.5 2,662.8 2,457.4 40.00 L-80 BTC-m INTERMEDIATE 7 6.28 25.2 8,870.0 6,952.6 26.00 L-80 BTC-m LINER 3 1/2 2.99 8,700.9 15,742.0 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 21.3 Set Depth … 8,753.1 Set Depth … 6,936.1 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd-mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 21.3 21.3 0.00 HANGER 10.850 FMC 4-1/2" x 11" tubing hanger (10.85" OD) FMC 135605- 0001 4.500 130.2 130.2 0.47 XO - Reducing 4.500 Crossover 4-1/2" 12.6 ppf L-80 IBT- m box x 3-1/2" 2.992 2,056.7 1,992.1 35.49 SAFETY VLV 5.176 3-1/2" Camco TRMAXX-5E w/ 2.812" "X" profile, (HYDRAULIC SLEEVE LOCKED OUT 4/6/18, FLAPPER LOCKED OUT 4/24/18) CAMCO 1004692 29 2.812 3,907.8 3,397.2 40.47 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG CAMCO KBMG 2.920 6,769.0 5,593.9 33.67 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG CAMCO KBMG 2.920 8,372.8 6,811.6 63.53 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG CAMCO KBMG 2.920 8,516.2 6,870.8 67.56 NIPPLE 4.540 HES "XN" nipple (2.813" profile 2/ 2.75" No-go) HES 2.813 8,711.5 6,928.4 78.42 LOCATOR 4.000 Baker 80-40 GBH locator Baker 2.970 8,743.1 6,934.4 79.65 SEAL ASSY 4.000 80-40 Bonded Seal assembly Baker 3.000 8,751.0 6,935.8 79.99 SEAL ASSY 4.000 80-40 Seal assembly w/ 1/2 mule shoe Baker 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,055.6 1,991.2 35.45 SLIP STOP 3.5" Slip Stop set on ISO Sleeve 4/6/2024 1.500 2,056.7 1,992.1 35.49 ISO-SLEEVE 2.812" ISO Sleeve (54" OAL) on 2.84" no-go sub with 7" extened packing, 2.85" chevron lower pkg, 2.875" chevron w/ o-rings and oversized 2.85" fruitenberg pkg upper (54" OAL) 4/6/2024 1.710 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,907.8 3,397.2 40.47 1 GAS LIFT GLV BK-5 1 1,765.0 11/17/2022 0.185 6,769.0 5,593.9 33.67 2 GAS LIFT GLV BK-5 1 1,833.0 11/17/2022 0.250 8,372.8 6,811.6 63.53 3 GAS LIFT OV BK 1 11/13/2022 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,700.9 6,926.2 78.02 PACKER 5.960 "HRD" ZXP Liner Top Packer Baker HRD ZXP Liner Top Packer 4.360 8,720.7 6,930.2 78.78 NIPPLE 5.260 "RS" Packoff Nipple Baker RS Packoff Nipple 4.260 8,753.4 6,936.2 80.09 XO BUSHING 5.000 Cross Over Bushing Baker XO Bushing 2.937 8,890.5 6,955.1 83.37 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 8,968.6 6,962.8 85.22 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 9,419.0 6,975.0 88.66 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 2.000") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 9,832.0 6,987.8 87.77 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 10,313.2 6,992.1 89.94 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.875") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 10,760.9 6,993.3 89.77 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 11,303.3 6,997.5 89.61 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.750") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 11,874.6 7,002.0 89.86 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 12,108.0 7,003.6 89.08 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.625") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 12,340.1 7,007.5 89.61 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 12,848.8 7,014.3 89.82 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.500") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 HORIZONTAL, CD3-199, 4/7/2024 5:51:10 AM Vertical schematic (actual) LINER; 8,700.9-15,742.0 SHOE; 15,735.8-15,742.0 PERFP; 15,695.0-15,705.0 APERF; 15,500.0-15,520.0 Swell Packer; 15,466.4-15,472.0 FRAC; 14,960.0 PERFP; 14,960.0-14,965.0 FRAC PORT; 14,959.8-14,965.0 APERF; 14,850.0-14,870.0 RPERF; 14,850.0-14,870.0 APERF; 14,700.0-14,720.0 Swell Packer; 14,445.3-14,451.0 APERF; 14,300.0-14,320.0 APERF; 14,200.0-14,220.0 FRAC PORT; 13,904.1-13,909.3 PERFP; 13,904.0-13,909.0 FRAC; 13,904.0 APERF; 13,100.0-13,120.0 PERFP; 12,849.0-12,854.0 FRAC; 12,849.0 FRAC PORT; 12,848.8-12,854.1 Swell Packer; 12,340.1-12,345.8 FRAC PORT; 12,108.0-12,113.3 PERFP; 12,108.0-12,113.0 FRAC; 12,108.0 Swell Packer; 11,874.6-11,880.3 FRAC PORT; 11,303.3-11,308.5 PERFP; 11,303.0-11,308.0 FRAC; 11,303.0 APERF; 11,000.0-11,020.0 FRAC PORT; 10,313.2-10,318.5 FRAC; 10,313.0 PERFP; 10,313.0-10,318.0 Swell Packer; 9,832.0-9,837.7 FRAC PORT; 9,419.0-9,424.3 PERFP; 9,419.0-9,424.0 FRAC; 9,419.0 APERF; 9,000.0-9,020.0 Swell Packer; 8,968.6-8,974.2 Swell Packer; 8,890.5-8,896.2 INTERMEDIATE; 25.2-8,870.0 Float Shoe; 8,867.9-8,870.0 Float Collar; 8,784.9-8,785.9 XO BUSHING; 8,753.4-8,755.0 SEAL ASSY; 8,751.0 SBE; 8,734.8-8,753.4 SEAL ASSY; 8,743.1 Landing Collar; 8,743.0-8,744.0 HANGER; 8,723.5-8,732.8 NIPPLE; 8,720.7-8,723.5 LOCATOR; 8,711.5 PACKER; 8,700.9-8,720.7 NIPPLE; 8,516.2 GAS LIFT; 8,372.8 GAS LIFT; 6,769.0 Collar; 5,324.9-5,327.3 GAS LIFT; 3,907.8 SURFACE; 26.5-2,662.8 Float Shoe; 2,660.6-2,662.8 Float Collar; 2,584.0-2,585.2 ISO-SLEEVE; 2,056.7 SAFETY VLV; 2,056.7 SLIP STOP; 2,055.6 CONDUCTOR; 31.0-114.0 HANGER; 26.5-26.7 Casing Hanger; 25.2-26.2 HANGER; 21.3 WNS PROD KB-Grd (ft) 28.00 RR Date 3/11/2011 Other Elev… CD3-199 ... TD Act Btm (ftKB) 15,742.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032063500 Wellbore Status PROD Max Angle & MD Incl (°) 91.91 MD (ftKB) 15,678.89 WELLNAME WELLBORECD3-199 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,390.7 7,027.8 88.42 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 13,904.1 7,025.2 90.51 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.375") Milled w/ 2.72" BOW 4/30/11 Packers Plus Frac Port 2.720 14,445.3 7,026.9 89.67 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 14,959.7 7,022.3 90.45 FRAC PORT 4.500 Ball Actuated Sleeve (Original ID 1.25". Milled to 2.68" on 3/2/21) Packers Plus Frac Port 2.680 15,466.4 7,015.2 90.75 Swell Packer 5.750 Water Activated Assembly, TAM Swell Packer TAM 2.960 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,000.0 9,020.0 6,965.2 6,966.5 3/29/2024 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 9,419.0 9,424.0 6,975.0 6,975.2 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 10,313.0 10,318.0 6,992.1 6,992.1 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 11,000.0 11,020.0 6,995.5 6,995.8 3/29/2024 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 11,303.0 11,308.0 6,997.5 6,997.6 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 12,108.0 12,113.0 7,003.6 7,003.7 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 12,849.0 12,854.0 7,014.3 7,014.3 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 13,100.0 13,120.0 7,019.1 7,019.7 3/29/2024 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 13,904.0 13,909.0 7,025.2 7,025.1 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 14,200.0 14,220.0 7,022.9 7,023.2 3/8/2023 6.0 APERF 2" PJO 6 SPF 60 DEG HSD. 14,300.0 14,320.0 7,025.2 7,025.5 3/16/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 14,700.0 14,720.0 7,026.4 7,026.1 3/8/2023 6.0 APERF 2" PJO 6 SPF 60 DEG HSD. 14,850.0 14,870.0 7,023.6 7,023.3 3/15/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 14,850.0 14,870.0 7,023.6 7,023.3 3/8/2023 6.0 RPERF 2" PJO 6 SPF 60 DEG HSD. 14,960.0 14,965.0 7,022.3 7,022.2 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 15,500.0 15,520.0 7,014.8 7,014.6 3/5/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 15,695.1 15,705.0 7,009.7 7,009.4 4/13/2011 1.0 PERFP Pre-Perforated Pup w (8) 1/2" holes @ mid jt Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,419.0 9,424.0 1 FRAC 4/13/2011 0.0 0.00 0.00 10,313.0 10,318.0 2 FRAC 4/13/2011 0.0 0.00 0.00 11,303.0 11,308.0 3 FRAC 4/13/2011 0.0 0.00 0.00 12,108.0 12,113.0 4 FRAC 4/13/2011 0.0 0.00 0.00 12,849.0 12,854.0 5 FRAC 4/13/2011 0.0 0.00 0.00 13,904.0 13,909.0 6 FRAC 4/13/2011 0.0 0.00 0.00 14,960.0 14,965.0 7 FRAC 4/13/2011 0.0 0.00 0.00 HORIZONTAL, CD3-199, 4/7/2024 5:51:11 AM Vertical schematic (actual) LINER; 8,700.9-15,742.0 SHOE; 15,735.8-15,742.0 PERFP; 15,695.0-15,705.0 APERF; 15,500.0-15,520.0 Swell Packer; 15,466.4-15,472.0 FRAC; 14,960.0 PERFP; 14,960.0-14,965.0 FRAC PORT; 14,959.8-14,965.0 APERF; 14,850.0-14,870.0 RPERF; 14,850.0-14,870.0 APERF; 14,700.0-14,720.0 Swell Packer; 14,445.3-14,451.0 APERF; 14,300.0-14,320.0 APERF; 14,200.0-14,220.0 FRAC PORT; 13,904.1-13,909.3 PERFP; 13,904.0-13,909.0 FRAC; 13,904.0 APERF; 13,100.0-13,120.0 PERFP; 12,849.0-12,854.0 FRAC; 12,849.0 FRAC PORT; 12,848.8-12,854.1 Swell Packer; 12,340.1-12,345.8 FRAC PORT; 12,108.0-12,113.3 PERFP; 12,108.0-12,113.0 FRAC; 12,108.0 Swell Packer; 11,874.6-11,880.3 FRAC PORT; 11,303.3-11,308.5 PERFP; 11,303.0-11,308.0 FRAC; 11,303.0 APERF; 11,000.0-11,020.0 FRAC PORT; 10,313.2-10,318.5 FRAC; 10,313.0 PERFP; 10,313.0-10,318.0 Swell Packer; 9,832.0-9,837.7 FRAC PORT; 9,419.0-9,424.3 PERFP; 9,419.0-9,424.0 FRAC; 9,419.0 APERF; 9,000.0-9,020.0 Swell Packer; 8,968.6-8,974.2 Swell Packer; 8,890.5-8,896.2 INTERMEDIATE; 25.2-8,870.0 Float Shoe; 8,867.9-8,870.0 Float Collar; 8,784.9-8,785.9 XO BUSHING; 8,753.4-8,755.0 SEAL ASSY; 8,751.0 SBE; 8,734.8-8,753.4 SEAL ASSY; 8,743.1 Landing Collar; 8,743.0-8,744.0 HANGER; 8,723.5-8,732.8 NIPPLE; 8,720.7-8,723.5 LOCATOR; 8,711.5 PACKER; 8,700.9-8,720.7 NIPPLE; 8,516.2 GAS LIFT; 8,372.8 GAS LIFT; 6,769.0 Collar; 5,324.9-5,327.3 GAS LIFT; 3,907.8 SURFACE; 26.5-2,662.8 Float Shoe; 2,660.6-2,662.8 Float Collar; 2,584.0-2,585.2 ISO-SLEEVE; 2,056.7 SAFETY VLV; 2,056.7 SLIP STOP; 2,055.6 CONDUCTOR; 31.0-114.0 HANGER; 26.5-26.7 Casing Hanger; 25.2-26.2 HANGER; 21.3 WNS PROD CD3-199 ... WELLNAME WELLBORECD3-199 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Kayla Junks at 9:58 am, Apr 05, 2023 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Susp Well Insp ❑ Plug Perforations Fracture Stimulate C Pull Tubing U Operations shutdown ❑ Performed: Install Whipstock Perforate J Other Stimulate ❑ Alter Casing Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well ❑ Coiled Tubing Ops ❑ Other: ❑ 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic _ Service ❑ 211-010 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20635-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372104, ADL 372105 CRU CD3-199 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field/Fiord Nechelik 11. Present Well Condition Summary: Total Depth measured 15,742 feet Plugs measured None feet true vertical 7,027 feet Junk measured None feet Effective Depth measured 15,742 feet Packer measured 14,993 feet true vertical 7,027 feet true vertical 6,717 feet Casing Length Size MD TVD Burst Collapse Conductor 86' 16" 114 114 Surface 2635' 9.625" 2663 2457 Intermediate 8870' 7" 8870 6953 Liner 7260' 3.5" 15742 7027 Perforation depth Measured depth Existing:9419-9424,1031110318,11303-11308,12108-12113,12849-12854, 13904 13909, 14960-14965,14300-14320', 14850-14870', 15500-15520', 15695-157052023 Now, 14.850'44.870-.18.700'-18,720' and 14.20044.220' MD True Vertical depth Exis tng:6975 975, 6992-6992, 69970997, 700&7003, 7014-7014, 7025-7025. 7022-7M2, 7W9-7009, 702b7025', 7023-7023', 7014-7015' 2023 New: 7024-7025, 7022-7022'. 6909-6906 Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8753' MD 6,936' TVD Packers and SSSV (type, measured and true vertical depth) Packe[HRD ZXP Liner Top Packer 8,700' MD 6,936' TVD SSSV-Cameo TRMAXX-5E 2056" MD 1,992' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 217 1530 53 1574 238 Subsequent to operation: 274 1490 32 1360 241 13b. Pools active after work: 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 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL LJ Electronic Fracture Stimulation Data ❑ GSTOR I I WINJ ❑ WAG ❑ GINJ 7 SUSP SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Digitally signed by Mark NIA Authorized Name and Mark Shulman Shulman Digital Signature with Date: Date: 2023.04.0216:44:30-08'00' Contact Name: Mark Shulman Contact Email: mark.shulman(S212.cOm Authorized Title: Sr. Production Engineer Contact Phone: (907) 263-3782 Sr Pet Eng: ISr Pet Geo: I ISr Res Eng: DSR-4/6/23 RBDMS JSB 040623 Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov CD3-199 Perforations DTTMSTART JOBTYP SUMMARYOPS PERFORATE WITH 2" POWERJET OMEGA HSD GUNS 6SPF 60 DEG PHASING. 3/8/2023 MAINTAIN WELL RUN 1 PERF FROM 14,850'-14,870'. RUN 2 PERF FROM 18,700' - 18,720% RUN 3 PERF FROM 14,200'-14,220'. READY FOR SLICKLINE TO RESET WRDP. 3/10/2023 MAINTAIN WELL SET 3.5" WRDP W/ NOGO SUB (OAL = 84", S/N: HCS-43) @ 2057' RKB; SET 3.5" SLIP STOP (OAL = 19") @ SAME ON TOP OF SSSV. PULLED SLIP STOP AND WRDP @ 2057' RKB. RE SET SET 3.5" WRDP W/ 3/11/2023 MAINTAIN WELL NOGO SUB (DAL = 84", S/N: HTS-685) @ 2057' RKB; SET 3.5" SLIP STOP (OAL = 19") @ SAME ON TOP OF SSSV. WN$ PROD WELLNAME CD3-199 WELLBORE CD3-199 �r�r�En� r'� do Well Attributes Man Angle&MD TD '-"Illliv� NaSka.IDC. Flay Name FI RD NE HELIK WeIIWre I�%IIIWI 510320635 Wellhore 5itlua PR D 141°) 1.91 MOIM1K91 15,6J8.89 Eum MKBI 15.742.0 [ov�mm Comment H35 (ppm) Naie AnnWailon Entl eaie KBGdtl IM1) 0.0. Gale Olhed Elev. ... LaM WO: 28.00 311112011 Luiry Hanger HANGER SLIP STO SAFETVVL .D MCul`",25M an shoe 2,eOO SUulASE 2u LIF calpcsaa We LIF SEAL FRAC X NRDP(19'Ol ) 2.'WRDP SET O SUB (OAL 84') OD) Valve l Lmn I OD I TRO Run I I I I I Pan Numlml Packer c1u31Btl Millec 1 Aclivel Packer w�a ') Millec 1 kPacked ueletl 'Millec 1 Acti Packed nueletl ') Millec Packed c0 nualetl ') Millec 1 c G r Packer WNS PROD WELLNAME CD3-199 WELL80RE CD3-199 ConocoPhillips Alaska. Inc. ...ire a.,, HANGER SLIP sT. stormy MD M Csi`", 258,t ,n sno.; 2,85D LIF Colhr,532I WS LIF SEPL FMC & Slots Packer 20'of shots. W Cbn 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Scale Inhibition Treatment ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,742 feet None feet true vertical 7,027 feet None feet Effective Depth measured 15,742 feet 8700 feet true vertical 7,027 feet 6926 feet Perforation depth (existing) MD: 9419-9424, 10313- 10318, 11303-11308, 12108-12113 MD: 12849-12854, 13904- 13909, 14960-14965, 15695- 15705 feet Measured depth feet TVD: 6975-6975, 6992- 6992, 6997-6997, 7003- 7003 TVD: 7014-7014, 7025-7025, 7022-7022, 7009-7009 feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth)3.5" L-80 8753' MD 6,936' TVD Packers and SSSV (type, measured and true vertical depth) Packer: "HRD" ZXP Liner Top Packer 8,700' MD 6926' TVD SSSV- Camco TRMAXX-5E 2056' MD 1,992' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Mark Shulman Contact Name:Mark Shulman Authorized Title:Sr. Production Engineer Contact Email:mark.shulman@cop.com Contact Phone:(907) 263-3782 WINJ WAG 1500 Water-Bbl MD 114 2663 8870 TVD 114 28 Oil-Bbl measured true vertical Packer 15742 3. Address: 4. Well Class Before Work: 214 Representative Daily Average Production or Injection Data 2346 Casing Pressure Tubing Pressure ADL 372104, ADL 372105 1001 779 CRU CD3-199 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-010 50-103-20635-00-00 N/A P.O. Box 100360, Anchorage, Alaska 99510 548 Gas-Mcf measuredPlugs Junk measured None 7260' None 5. Permit to Drill Number: 1400 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 231 Size Colville River Field/Fiord Nechelik Surface Intermediate Liner Authorized Signature with date: Authorized Name: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Casing Conductor 16" 9.625" 7" 3.5" Length 86' 2635' 8870' 2457 6953 7027 Burst Perforation depth 14300-14320', 14850-14870', 15500-15520' 7025-7025', 7023-7023', 7014-7015' 2. Operator Name Senior Engineer:Senior Res. Engineer: Collapse t Fra O g g g l O g 6. A GJ L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:05 am, Apr 12, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.04.12 09:40:45 -08'00' Alpine Oil Pool SFD 4/15/2021VTL 5/5/21 RBDMS HEW 4/12/2021 SFD SFD 4/15/2021 DSR-4/12/21 CD3-199 Summary of Operations Perforations DTTMSTART JOBTYP Summary OPS 3/5/2021 ZONAL Perforated from 15,520'-15,500' with 2" 6 SPF 60* 2006PJ Omega gun. 3/15/2021 ZONAL Perforate with 2.0" PJ Omega 6spf 60 deg phasing from 14850’-14870' RKB. 3/16/2021 ZONAL Perforate from 14,300'-14320' with 2" PJ Omega 6spf 60 deg phasing charges. JOB COMPLETE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD3-199 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated milled out Frac sleeve and add perfs 3/16/2021 CD3-199 famaj Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 31.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 26.5 Set Depth (ftKB) 2,662.8 Set Depth (TVD) … 2,457.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-m Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 25.2 Set Depth (ftKB) 8,870.0 Set Depth (TVD) … 6,952.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-m Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 8,700.9 Set Depth (ftKB) 15,742.0 Set Depth (TVD) … Wt/Len (l… 9.30 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,700.9 6,926.2 78.02 PACKER "HRD" ZXP Liner Top Packer 4.360 8,720.7 6,930.2 78.78 NIPPLE "RS" Packoff Nipple 4.260 8,723.5 6,930.7 78.89 HANGER Flex-Lock Liner Hanger 4.360 8,734.8 6,932.9 79.33 SBE Seal Bore Extension 4.000 8,753.4 6,936.2 80.09 XO BUSHING Cross Over Bushing 2.937 8,890.5 6,955.1 83.37 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 8,968.6 6,962.8 85.22 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 9,419.0 6,975.0 88.66 FRAC PORT Ball Actuated Sleeve (Original ID 2.000") Milled w/ 2.72" BOW 4/30/11 2.720 9,832.0 6,987.8 87.77 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 10,313.2 6,992.1 89.94 FRAC PORT Ball Actuated Sleeve (Original ID 1.875") Milled w/ 2.72" BOW 4/30/11 2.720 10,760.9 6,993.3 89.77 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 11,303.3 6,997.5 89.61 FRAC PORT Ball Actuated Sleeve (Original ID 1.750") Milled w/ 2.72" BOW 4/30/11 2.720 11,874.6 7,002.0 89.86 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 12,108.0 7,003.6 89.08 FRAC PORT Ball Actuated Sleeve (Original ID 1.625") Milled w/ 2.72" BOW 4/30/11 2.720 12,340.1 7,007.5 89.61 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 12,848.8 7,014.3 89.82 FRAC PORT Ball Actuated Sleeve (Original ID 1.500") Milled w/ 2.72" BOW 4/30/11 2.720 13,390.7 7,027.8 88.42 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 13,904.1 7,025.2 90.51 FRAC PORT Ball Actuated Sleeve (Original ID 1.375") Milled w/ 2.72" BOW 4/30/11 2.720 14,445.3 7,026.9 89.67 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 14,959.7 7,022.3 90.45 FRAC PORT Ball Actuated Sleeve (Original ID 1.25". Milled to 2.68" on 3/2/21) 2.680 15,466.4 7,015.2 90.75 Swell Packer Water Activated Assembly, TAM Swell Packer 2.960 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 21.3 Set Depth (ft… 8,753.1 Set Depth (TVD) (… 6,936.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd-mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.3 21.3 0.00 HANGER FMC 4-1/2" x 11" tubing hanger (10.85" OD) 4.500 130.2 130.2 0.47 XO - Reducing Crossover 4-1/2" 12.6 ppf L-80 IBT-m box x 3-1/2" 2.992 2,056.7 1,992.1 35.49 SAFETY VLV 3-1/2" Camco TRMAXX-5E w/ 2.812" "X" profile, (HYDRAULIC SLEEVE LOCKED OUT 4/6/18, FLAPPER LOCKED OUT 4/24/18) 2.812 8,516.2 6,870.8 67.56 NIPPLE HES "XN" nipple (2.813" profile 2/ 2.75" No-go) 2.813 8,711.5 6,928.4 78.42 LOCATOR Baker 80-40 GBH locator 2.970 8,743.1 6,934.4 79.65 SEAL ASSY 80-40 Bonded Seal assembly 3.000 8,751.0 6,935.8 79.99 SEAL ASSY 80-40 Seal assembly w/ 1/2 mule shoe3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,419.0 9,424.0 6,975.0 6,975.2 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 10,313.0 10,318.0 6,992.1 6,992.1 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 11,303.0 11,308.0 6,997.5 6,997.6 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 12,108.0 12,113.0 7,003.6 7,003.7 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 12,849.0 12,854.0 7,014.3 7,014.3 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 13,904.0 13,909.0 7,025.2 7,025.1 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 14,300.0 14,320.0 7,025.2 7,025.5 3/16/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 14,850.0 14,870.0 7,023.6 7,023.3 3/15/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. HORIZONTAL, CD3-199, 3/16/2021 5:13:29 AM Vertical schematic (actual) LINER; 8,700.9-15,742.0 PERFP; 15,695.0-15,705.0 APERF; 15,500.0-15,520.0 PERFP; 14,960.0-14,965.0 FRAC; 14,960.0 APERF; 14,850.0-14,870.0 PERFP; 13,904.0-13,909.0 FRAC; 13,904.0 PERFP; 12,849.0-12,854.0 FRAC; 12,849.0 FRAC; 12,108.0 PERFP; 12,108.0-12,113.0 PERFP; 11,303.0-11,308.0 FRAC; 11,303.0 FRAC; 10,313.0 PERFP; 10,313.0-10,318.0 PERFP; 9,419.0-9,424.0 FRAC; 9,419.0 INTERMEDIATE; 25.2-8,870.0 SEAL ASSY; 8,751.0 SEAL ASSY; 8,743.1 LOCATOR; 8,711.5 NIPPLE; 8,516.2 GAS LIFT; 8,372.8 GAS LIFT; 6,769.0 GAS LIFT; 3,907.8 SURFACE; 26.5-2,662.8 SAFETY VLV; 2,056.7 CONDUCTOR; 31.0-114.0 HANGER; 21.3 WNS PROD KB-Grd (ft) 28.00 Rig Release Date 3/11/2011 CD3-199 ... TD Act Btm (ftKB) 15,742.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032063500 Wellbore Status PROD Max Angle & MD Incl (°) 91.91 MD (ftKB) 15,678.89 WELLNAME WELLBORECD3-199 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 14,300.0 14,320.0 7,025.2 7,025.5 3/16/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 14,850.0 14,870.0 7,023.6 7,023.3 3/15/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. Alpine SFD 4/15/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,960.0 14,965.0 7,022.3 7,022.2 4/13/2011 1.0 PERFP FRAC Port - Single 4' Slot/FRAC Port 15,500.0 15,520.0 7,014.8 7,014.6 3/5/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 15,695.1 15,705.0 7,009.7 7,009.4 4/13/2011 1.0 PERFP Pre-Perforated Pup w (8) 1/2" holes @ mid jt Frac Summary Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 4/13/2011 Top Depth (ftKB) 9,419.0 Btm (ftKB) 9,424.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 2 Start Date 4/13/2011 Top Depth (ftKB) 10,313.0 Btm (ftKB) 10,318.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 3 Start Date 4/13/2011 Top Depth (ftKB) 11,303.0 Btm (ftKB) 11,308.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 4 Start Date 4/13/2011 Top Depth (ftKB) 12,108.0 Btm (ftKB) 12,113.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 5 Start Date 4/13/2011 Top Depth (ftKB) 12,849.0 Btm (ftKB) 12,854.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 6 Start Date 4/13/2011 Top Depth (ftKB) 13,904.0 Btm (ftKB) 13,909.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 4/13/2011 Proppant Designed (lb) Proppant In Formation (lb) Stg # 7 Start Date 4/13/2011 Top Depth (ftKB) 14,960.0 Btm (ftKB) 14,965.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,907.8 3,397.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/10/2011 2 6,769.0 5,593.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/10/2011 3 8,372.8 6,811.6 CAMCO KBMG 1 GAS LIFT OV BK 0.250 8/5/2016 HORIZONTAL, CD3-199, 3/16/2021 5:13:30 AM Vertical schematic (actual) LINER; 8,700.9-15,742.0 PERFP; 15,695.0-15,705.0 APERF; 15,500.0-15,520.0 PERFP; 14,960.0-14,965.0 FRAC; 14,960.0 APERF; 14,850.0-14,870.0 PERFP; 13,904.0-13,909.0 FRAC; 13,904.0 PERFP; 12,849.0-12,854.0 FRAC; 12,849.0 FRAC; 12,108.0 PERFP; 12,108.0-12,113.0 PERFP; 11,303.0-11,308.0 FRAC; 11,303.0 FRAC; 10,313.0 PERFP; 10,313.0-10,318.0 PERFP; 9,419.0-9,424.0 FRAC; 9,419.0 INTERMEDIATE; 25.2-8,870.0 SEAL ASSY; 8,751.0 SEAL ASSY; 8,743.1 LOCATOR; 8,711.5 NIPPLE; 8,516.2 GAS LIFT; 8,372.8 GAS LIFT; 6,769.0 GAS LIFT; 3,907.8 SURFACE; 26.5-2,662.8 SAFETY VLV; 2,056.7 CONDUCTOR; 31.0-114.0 HANGER; 21.3 WNS PROD CD3-199 ... WELLNAME WELLBORECD3-199 15,500.0 15,520.0 7,014.8 7,014.6 3/5/2021 6.0 APERF 2.0" Perf Gun, 6 SPF, 60 deg, 2006 PJ Omega HMX, 7.3 gm, 0.22" Ent hole, 21.8" Penetration. 20' of shots. 15 695 1 15 705 0 7 009 7 7 009 4 4/13/2011 1 0 PERFP P P f t d P (8) • • 21 1Q1O 29389', WELL LOG TRANSMITTAL#904803977 To: Alaska Oil and Gas Conservation Comm. June 11, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RECEIVED E�+^c'r, E D JUN 2 0 2018 RE: Leak Detect Log: CD3-199 AOGCC Run Date: 4/25/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 CD3-199 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20635-00 Leak Detect Log 1 Color Log 50-103-20635-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Fanny Sari SCANNED JUN 2 5 PM' 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Wi �Date: Signed: Image Project Well History File Cover Page 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. ai L - 010.. Well History File Identifier Organizing (done) Two-sided III 111111 111111111 ❑ Rescan Needed III 1111 N II II1 II1 7CAN DIGITAL DATA OVERSIZED (Scannable) or Items: ❑ Diskettes, No. i❑ Ma s: Greyscale Items: ❑ Other, No/Type: they Items Scannable by a Large Scanner Joqs ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: W V. /ii,,. /s/ mf Project Proofing 1111111111111111 BY: AZIP Date: (OI /s/ IA a Scanning Preparation 1-1- x 30 = 'a O + (p = TOTAL PAGES / a(D (Count does not include cover sheet) r�/I,BY: MP Date: (pj� /s/ �/f fT Production Scanning II IIIIIIIIII IIIII Stage 1 Page Count from Scanned File: (Count does include cover sheet) 7 Pa•e Count Matches Number in Scanning Preparation: YES NO BY: AP Date: bfqfI4.. Is! Ili fD Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. MI1111111111 ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 11E11111 IIIIII I 0O m C O p °ro H _ =ea lIJ 0 LL a' ce Lo ca LL O 01CD Z O �� W u cc LLI l W N - a2Oa2 ix-as C a'-=ZU v Q c ilii, °� EI Oaa� a� ao v) co E USX��a rn OQ �Q H C a) I 2 U - oiz au_ 55,Z OZ Z o =aaU ca0 I- >H Oa zzoa 20 HU E. - 1 o a C d 0 0 > a m JO O N N N N 1 U — Q J N N N N y Z CO CO CO CO C 7 C C C C 1 '� i z a) a) a) a) E j il N� U) ( a) OO O O 0 0 o Y� I U < N N N N d g COm C N. N N- N d a`) Z Z Uj - m Lt) LO LO c P.., .0H4 0 ca m I 1 W d v) Z S I •C CD CD CO_ _M 0 c,. I U U) N N a W Z -J a V 00 o > 0 a) N Z ct 0. C ° ° Z I-- o Q CC a) > `� o am R = co 1 i ill aN o f Z _1 2 U U ii2o � N a) 0 O Nr QpO)AfN to N N V N U E J 0 V) J I r Q a 0 0. H a - co 5 O_ 0 1 To I G LL N 1 1 1 I m 2 M c _j Iii y I Q J Vg 1— N O < ZI In 0 Lu cc w . w CD a) U O C y N N E I J CCO V/ y N j Z c Uct CL CC i _ j 2 w C C C 0 I a) c I E a) 'V 'U 'U O Z 1 U) -o -o -o O CeNJ c c c + I y E Z o O ZO ,- H a o )1.6. 1. &), t f 1 co c 0 >- a Z t p W O Z N d re • cc O 0 N :r O < o E a E Z r. I LL E E E E v = N Z 2 re V ... ,.�" y 10 co J > I O y Z N U - eaOy le) 11 49 ., I Z W0 �U ° H U N E a y J \ U p - n T° ' O O 0 O N M 0 Z O N r, Urk O 5 .— s- 6 „-) O C? Z a a J o U z N_ N fC 11 CO 0 J Ce Q C d Oa O.. U J_ W = a ce O U W 0Z U 0 0 o Z QCO N cu O. N ON O.C r G O O N O N E U � U J < M U I- 0 N CO 2 M p 111 J J a) > too Q J U o r a) Q C a z E _____5 Q m U E ca Z m o r o> m O H -0 3 NN N r4 D C Ts. E E 0 a 2 U ✓ . . ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012 O 1 O )-11 Commissioner Dan Seamount - ) — 1 (1 Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043,if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 5/15/2012 WD,CD2,CD3,CD4,PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal WD-02 50103202850000 1982580 2' n/a 2' n/a 13.6 4/11/2012 CD2-77 50103206290000 2101790 SF n/a 17" n/a 2.1 4/13/2012 CD3-128 50103206380000 2110370 21' n/a 21' n/a 90.7 4/13/2012 CD3-198 50103206370000 2110240 28" n/a 28" n/a 47.6 4/13/2012 () CD3-199 50103206350000 2110100 SF n/a 11" n/a 2.9 4/13/2012 CD4-03 50103206410000 2111130 29" n/a 29" n/a 9.4 4/11/2012 C04-298 50103206230000 2101300 28" n/a 28" n/a 28.9 4/11/2012 ' STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other r Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r d' 211-010 3.Address: 6.API Number: Stratigraphic r Service 1--- P. O. Box 100360,Anchorage,Alaska 99510 +r 50-103-20635-00 T.4;:)0 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 372104,372105 ,CD3-199 9. Field/Pool(s): Colville River Field/Fiord Oil Pool 10.Present Well Condition Summary: Total Depth measured 15472' feet Plugs(measured) none (measured)vertical 7008' feet Junk( ) none Effective Depth measured 15472' feet Packer(measured) 8701,and 9 swell packers P true vertical 7008' feet (true vertucal) 6926 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 114' 114' Surface 2630' 9.625" 2663' 2452' Intermediate 8835' 7" 8870' 6950' Liner 7041' 3.5" 15742' 7008' RECEIVE ' Perforation depth: Measured depth: liner from 8701'-15742' MAY 0 9 2011 True Vertical Depth: 6926'-7008' Alaska Oil&Gax Cans.&omission Tubing(size,grade,MD,and TVD) 3.5", L-80,8753'MD,6936 TVD Af OQf bge Packers&SSSV(type,MD,and ND) HRD ZXP Liner Top Packer @ 8701'MD,6926'TVD and 9 TAM swell packers(see schematic) CAMCO TRMAXX-5E SSSV @ 2057'MD, 1992'TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): 9419'-14965'MD Treatment descriptions including volumes used and final pressure: pumped 786,115#of 16/30 Colorado White Sand 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation na Subsequent to operation 1613 2509 80 -- 364 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r — Service r Stratigraphic r 15.Well Status after work: ✓Oil gro Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG E GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-089 Contact T. Senden @ 265-1544 Printed Name \T. nden Title Wells Engineer • Signature ! Phone: 265-1544 Date 011 I MAY � ��_ . Form 10-404 Revised 10/2010 RBDMS 20' s --,•//t/ Submit Original Only CD3-199 Well Work Summary DATE SUMMARY 4/8/11 SET CATCHER @ 8498' SLM. PUL__D SOV @ 8373' RKB. PUMPED 220 BBL ilHIBITED SW AND 70 BBLS DIESEL THEN U-TUBE. 4/9/11 SET SPARTEK SPG @ 8373' RKB. LRS PERFORMING MITIA. PASSED. IN PROGRESS. 4/10/11 PULLED CATCHER @ 8498' SLM. PULLED BALL& ROD/RHC BODY @ 8517' RKB. PERFORMED SBHPS @ 8600' RKB (PSI=3642 TEMP=165) READY FOR FRAC.. 4/11/11 Rigged-up frac equipment to well. Job delayed due to late start and cold-weather issues. Due to length of pump time, decision made to push frac to tomorrow with fresh start in the a.m.. 4/12/11 FRAC EQUIPMENT PROBLEMS, DELAY JOB FOR THE FOLLOWING DAY. 4/13/11 ALPINE NECHELIK SAND FRAC. PUMPED A TOTAL OF 786,115 LBS OF 16/30 COLORADO WHITESAND PLACED BEHIND PIPE. FRAC PUMPED TO 92% DESIGN. FLUSH JOB TO COMPLETION, WITH 27 BBLS XL GEL, 10 BBL LINEAR GEL AND 53 BBLS DIESEL FREEZE PROTECTION. 4/15/11 PULLED ISO SLEEVE @ 2056' RKB. DRIFT TBG TO 2.68"TO 8705' SLM. CATCHER SUB DEPLOYED. PULLED 1"SPG @ 8372' RKB &SET 1"OV( 1/4" PT) @ SAME. PULLED CATCHER SUB @ 8516' RKB. RESET ISO SLEEVE @ 2056' RKB. COMPLETE 4/27/11 TBG OPEN 2.85"TO 2056' RKB, PULLED 2.81 ISO SLEEVE @ 2056' RKB. COMPLETE MOVE TO CD3-122 4/29/11 RIG UP SLB. CTU 5 ON CD3-199, MILL TOP 3 FRAC PORT BALL SEATS AT 2419' 10313'AND 11303' LIFTED FILL FROM WELLBORE USING NITROGEN AND GEL PILL SWEEPS.. HEAVY RETURNS OF FRAC SAND WAS SEEN. RTN IN A.M. 4/30/11 MILLED OUT FRAC SLEEVES @ 12,108, 12849 AND 13,904. CLEANED OUT WELLBORE TO 14,074 CTMD (MAX COIL LENGTH). WASN'T ABLE TO MILL THE LAST FRAC SLEEVE @ 14,960 DUE TO COIL LENGTH. HEAVY FRAC SAND IN RETURNS. FREEZE PROTECTED WELL. JOB COMPLETE. 5/4/11 PERFORM N2 FILL CLEAN OUT TO END OF COIL AT 14061 CTMD, MEDIUM AMOUNT OF SAND IN RTNS, WELL IS ONLINE, JOB COMPLETE. vet- i-fow 1 7.u,., SCJ•t.,4 ��<� i WNS CD3-199 ConocoPhillips Y I Well Attributes Max Angie 8 MD i TD A!/i59aInc Wall boreAPAWI Field Name (WellStat Incl(1 TAD(ftKB) Ad 01,0 SOB) LurfacaP'FNIkp1 501032063500 FIORD NECHELIK PROD 91.91 1 15,678.89 15./42 0 Comment H2S(ppm) Date Annotation E d Date KB-CM(ft) R19 Release Date welLCort09 NORI7RNTni_fiR3-.159.M7?120U e.53.02�M SSSV T_RDP _ I __last WO: I _ (_---28.00 3/11,2011 Sclt&neac-CPAnnotation Depth 19K6) End Date An tht on Last Mod By End Date HANGER.21 Last Tag: l _ [Rev Reason:_FRAC,GLV C/O 1.__Imosbor -1 4/17/2011 Casing Strings_ Y, MP Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd nna •��..aggi.-istryiNn :; i V ' .-,.-i, CONDUCTOR 16 15.250 31.0 114.0 114.0 62.50 H-40 Welded i, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top MITI SURFACE 95/8 8.835 26.5 2,662.8 2,457.3 40.00 L-80 BTC-m CONDUCTOR. ' Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(ND)...String Wt...String...Sting Top Thrd 31-114 Y INTERMEDIATE 7 6.276 25.2 8,870.0 6,952.5 26.00 L-801 BTC-m SAFETY VLV, Ilk Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt. String...String Top Thrd 2.057 LINER 3 1/2 12 992 8,700 9 15,742 0 9 30 L-80 SLHT ISO SLEEVE. - 2,057 - Liner: Details Top Depth._.__...... (ND) Top Incl Nomi... 2 Top(ftKB) ( ) 1') Item Description Comment ID(in)SURFACE, I 8,700.9 6,925.5 17.88 PACKER "HRD'VP Liner Top Packer 4.360 2Gz,683 8,720.7 6,930.0 78.71 NIPPLE "RS"Packoff Nipple 4.260 GAS LE•8 8,723.5 6,930.6 78.83 HANGER Flex-Lock Liner Hanger 4.360 p 8,734.8 6,932.8 79.30 SBE Seal Bore Extension 4.000 I! 8,753.5 6,936.2 80.09 XO BUSHING Cross Over Bushing 2.937 i 8,890.5 6952.3 82.71 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 GAS LIFT, -.GAS6.769- 8,968.6 6,962.8 85.12 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 6,769 9,419.0 6,975.0 88.66 FRAC PORT Ball Actuated Sleeve(2 000") 2.000 9,832.0 6,987.1 87.79 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 GAS LIFT, 8.373 el"! 10,313.2 6,094.3 91.78 FRAC PORT Ball Actuated Sleeve(1.875") 1.875 10,760.9 6,993.3 89.82 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 NIPPLE,8,518 11,303.3 6,997.5 89.49 FRAC PORT Ball Actuated Sleeve(1.750") 1.750 11,874.7 7,002.1 90.00 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 LOCATOR,_. 8,711 -- 12,108,0 7,002.7 88.19 FRAC PORT Ball Actuated Sleeve(1.625") 1.625 12,340.1 7,007.5 89.61 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 12,848.9 7,014.3 89.82 FRAC PORT Ball Actuated Sleeve(1.500") 1.500 1 t- - SEAL A8,7SS43 Y,_ 13,390.7 7,027.8 88.24 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 SEAL ASSY, 13,904.1 7,025.1 90.51 FRAC PORT Ball Actuated Sleeve(1.375") 1.375 8.751 14,445.3 7,025.3 88.52 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 Itilanir 14,959.8 7,021.4 89.54 FRAC PORT Ball Actuated Sleeve(1.25") 1.250 . ! 15,466.4 7,015.3 90.75 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 NTERMEDIATE, l Tubing Strings 25-8,870 Tubing Description String 0....ZStrng ID,.lTop rill(B) JSeDepth(f,.IS`'et Depth(ND) !String W_-_t.. String..Stn g Top Thrd TUBING 31/2 2.992 21.3 87531 6,936.19.30 L-80 EUE8rdmod_ Completion Details Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) I") Item Description Comment ID(in) 21.3 21.3 -0.03 HANGER FMC 4-1/2"x 11'tubing hanger(10.85"OD) 4.500 FRAC,9,619 , , 130.2 130.2 0.47 XO-Reducing Crossover4-1/2"12.6 ppf L-80 IBT-m box x 3-1/2"9.3 ppf L-80 EUE-m 2.992 On 2,056.7 1,992.1 XX- 35.49 SAFETY VLV 3.1/2'Camco TRMA5E w/2.812""X"profile,1/4"single control line 2.812 8,516.2 6,865.7 66.96 NIPPLE HES"XN"nipple(2.813"profile 2/2.75"No-go) 2.813 8,711.5 6,928.0 78.32 LOCATOR Baker 80-40 GBH locator 2.970 8,743.1 6,934.4 79.65 SEAL ASSY 80-40 Bonded Seal assembly 3.000 FRAC,,0.3,3 1 I 8,751.0 6,935.8 79.99 SEAL ASSY 80-40 Seal assembly w/1/2 mule shoe 3.000 Other In HoleIINireline retrievable plugs,valves,pumps fish etc.)__ Top Depth -----.. °VD) Top Incl Top(ftKB) (ftKB) (") Description Comment Run Date ID(in) I 2,056.7 1,992.1 35.49 ISO SLEEVE ISO SLEEVE SET IN SSSV 4/15/2011 FRAC,11,303 Stimulations&'Treatments Bottom Min Top Max Btrn Top Depth Depth Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 9,419.0 14,965.0 6,975.0 6,975.2 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC FRAC,12,108 THRU SLEEVES 9,419.0 14,965.0 6,994.3 6,994.0 FRAC 4/13/2017 PUMPED 16/30 COLORADO WHITE SAND FRAC THRU SLEEVES 9,419.0 14,965.0 6,997.5 6,997.5 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC THRU SLEEVES 9,419.0 14,965.0 7,002.7 7,002.9 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC THRU SLEEVES 9,419.0 14,965.0 7,014.3 7,014.3 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC FRAC,12,849 THRU SLEEVES 9,419.0 14,965.0 7,025.1 7,025.1 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC _ THRU SLEEVES 9,419.0 14,965.0 7,021.4 7,021.5 FRAC 4/13/2011 PUMPED 16/30 COLORADO WHITE SAND FRAC THRU SLEEVES Notes General8kSafety rFRAC,13,904 End D to Annotat e 3/21/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 FRAC,14,960 Mandrel Details oTopDep[h Top Port (TV0) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (7 Make Model (in) SeryType Type (in) (ps)) Run Date Com...1 3,907.8 3,397.1 40.26 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/10/2011 TD 15742 2 6,769.0 5,594.0 33.54 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 0.0 3/102011 LINER, 3 8,372.8 6,811.6 63.53 CAMCO KBMG 1 GAS LIFT OV INT 0.250 0.0 4/16/2011 8,701-15,742' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil a • Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 11,2011 • 211-010/ • 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 February 7,2011 50-103-20635-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1387 FSL,661'FEL,Sec.5,T12N,R5E, UM • March 6,2011 II ' CD3-199 • Top of Productive Horizon: 8. KB(ft above MSL) 0,12.8'RKB 15.Field/Pool(s): 2432'FNL,2188'FEL,Sec.5,T12N, R5E, UM GL(ft above MSLfor L140'AMSL Colville River Field Total Depth: 9.Plug Back Depth(MD+ND): 1942'FNL,2528'FWL,Sec.9,T12N,R5E, UM 15472'MD/7008'TVD Fiord Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-388383.5' y- 6003879 • Zone-4 • 15742'MD/7008'TVD • ADL 372104,372105 " TPI: x-386874 y- 6005362 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-391531 y- 6000503 Zone-4 2057'MD/1992'TVD LAS2112 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1300'MD/1297'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 28' 114' 28' _ 114' 24" Pre-installed 9.625" 40# L-80 28' 2663' 28' 2457' 12.25" 308 sx AS Lite,272 sx Class G 7" 26# L-80 28' 8870' 28' 6953' 8.75" 215 sx Class G,186 sx Class G 3.5" 9.3# L-80 8701' 15742' 6926' 7008' 6.125" liner with swell packers 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 8753' 8701'MD/6926'TVD liner from 8701'-15742'MD 6926'-7008'ND ,i:,OM j EilOM ` 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. *" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED t 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical resultpECE D NONE APR 0 8 2011 R DMS APR d'8 2011 Mao Oil&fins Cons.Commission 8 �=9� Ancnorege Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 1. u��•11 Submit original only 11nj 4;Z2j l 28. GEOLOGIC MARKERS(List all formations and rr aiKers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1300' 1297' needed,and submit detailed test information per 20 AAC 25.071. C-30 2696' 2482' C-20 3211' 2871' K-3 4559' 3888' K-2 --V(114A"Ic- 4789' 4063' Nanuq 7176' 5950' K-1 8150' 6699' Kuparuk C 8307' 6781' Nechelik 8782' 6941' N/A Formation at total depth: K2 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson©265-6318 Printed NameG Alvord Title: Alaska Drilling Manager 7f LP Signature Phone 263-4619 Date Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ► fl 0 kgk a t 4 ConocoPhiIII° ps(Alaska) Inc. Western North Slope I I CD3 Fiord Pad 0 IIt CD3-199 501032063500 A ti Sperry Drilling 00, Definitive Survey Report P 14 March, 2011 5 14 PI 4FS ty. x r0 *0 , t r • ► HALLIBURTON Sperry CJr iii n r v ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.40ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-199 Well Position +N/-S 0.00 ft Northing: 6,003,878.77 ft Latitude: 70°25' 10.386 N +EI-W 0.00 ft Easting: 388,383.47 ft Longitude: 150°54'33.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft L Wellbore CD3-199 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2010 2/7/2011 20.75 80.83 57,605 Design CD3-199 Audit Notes: i Version: 1.0 Phase: ACTUAL Tie On Depth: 27.60 Vertical Section: Depth From(TVD) i-N/-S +E/-W Direction (ft) (ft) (ft) (0) 27.60 0.00 0.00 143.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 78.00 1,000.00 CD3-199 Gyro(CD3-199) CB-GYRO-SS Camera based gyro single shot 2/8/2011 12:0C 1,042.97 2,617.66 CD3-199 MWD(R200)(CD3-199) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/8/2011 12:OC 2,685.35 8,840.63 CD2-199 MWD(R300)(CD3-199) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/12/2011 12:C 8,889.47 15,678.89 CD3-199 MWD(R600)(CD3-199) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/28/2011 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing, Easting DLS Section (ft) (0) (°p (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.60 0.00 0.00 27.60 -12.80 0.00 0.00 6,003,878.77 388,383.47 0.00 0.00 UNDEFINED 78.00 0.24 320.06 78.00 37.60 0.08 -0.07 6,003,878.86 388,383.40 0.48 -0.11 CB-GYRO-SS(1) 113.00 0.26 307.66 113.00 72.60 0.19 -0.18 6,003,878.96 388,383.29 0.16 -0.26 CB-GYRO-SS(1) 143.00 0.63 286.01 143.00 102.60 0.27 -0.39 6,003,879.05 388,383.08 1.33 -0.45 CB-GYRO-SS(1) 173.00 0.80 280.92 173.00 132.60 0.36 -0.75 6,003,879.14 388,382.72 0.60 -0.74 CB-GYRO-SS(1) 263.00 1.34 5.07 262.98 222.58 1.53 -1.28 6,003,880.32 388,382.21 1.65 -1.99 CB-GYRO-SS(1) 355.00 2.41 12.42 354.93 314.53 4.49 -0.77 6,003,883.27 388,382.77 1.19 -4.04 CB-GYRO-SS(1) 447.00 3.49 11.41 446.81 406.41 9.12 0.20 6,003,887.89 388,383.81 1.18 -7.16 CB-GYRO-SS(1) 540.00 4.71 13.15 539.57 499.17 15.61 1.63 6,003,894.36 388,385.33 1.32 -11.49 CB-GYRO-SS(1) 632.00 5.01 6.68 631.24 590.84 23.28 2.96 6,003,902.01 388,386.77 0.68 -16.81 CB-GYRO-SS(1) 723.00 5.21 9.31 721.88 681.48 31.30 4.09 6,003,910.01 388,388.03 0.34 -22.54 CB-GYRO-SS(1) 3/14/2011 9:16:44AM Page 2 COMPASS 2003,16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.40ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Survey I Map Map Vertical MD Inc Azi TVD TVDSS +NI-S -FIE/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1001 (ft) Survey Tool Name 815.00 4.38 20.33 813.56 773.16 38.72 5.99 6,003,917.40 388,390.03 1.34 -27.32 CB-GYRO-SS(1) 908.00 3.78 20.01 906.32 865.92 44.93 8.27 6,003,923.57 388,392.41 0.65 -30.91 CB-GYRO-SS(1) 1,000.00 5.06 347.60 998.06 957.66 51.75 8.43 6,003,930.38 388,392.68 2.99 -36.25 CB-GYRO-SS(1) 1,042.97 5.04 341.51 1,040.86 1,000.46 55.39 7.43 6,003,934.04 388,391.72 1.25 -39.76 MWD+IFR-AK-CAZ-SC(2) 1,136.64 5.02 326.12 1,134.18 1,093.78 62.69 3.84 6,003,941.39 388,388.25 1.44 -47.76 MWD+IFR-AK-CAZ-SC(2) 1,228.78 5.63 315.74 1,225.92 1,185.52 69.27 -1.56 6,003,948.06 388,382.94 1.23 -56.27 MWD+IFR-AK-CAZ-SC(2) 1,320.17 8.42 308.99 1,316.62 1,276.22 76.70 -9.89 6,003,955.60 388,374.72 3.18 -67.21 MWD+IFR-AK-CAZ-SC(2) 1,413.70 11.05 307.78 1,408.79 1,368.39 86.50 -22.30 6,003,965.59 388,362.46 2.82 -82.50 MWD+IFR-AK-CAZ-SC(2) 1,506.41 15.50 303.02 1,499.01 1,458.61 98.70 -39.72 6,003,978.05 388,345.23 4.94 -102.73 MWD+IFR-AK-CAZ-SC(2) 1,600.21 19.33 304.88 1,588.49 1,548.09 114.41 -62.97 6,003,994.10 388,322.22 4.13 -129.27 MWD+IFR-AK-CAZ-SC(2) 1,692.02 23.16 307.89 1,674.05 1,633.65 134.20 -89.70 6,004,014.29 388,295.79 4.34 -161.16 MWD+IFR-AK-CAZ-SC(2) 1,786.58 26.44 308.38 1,759.88 1,719.48 158.69 -120.88 6,004,039.24 388,264.98 3.48 -199.49 MWD+IFR-AK-CAZ-SC(2) 1,877.59 28.79 309.83 1,840.51 1,800.11 185.32 -153.60 6,004,066.35 388,232.67 2.69 -240.44 MWD+IFR-AK-CAZ-SC(2) 1,969.81 32.22 309.26 1,919.96 1,879.56 215.11 -189.70 6,004,096.67 388,197.02 3.73 -285.96 MWD+IFR-AK-CAZ-SC(2) 2,063.12 35.73 311.25 1,997.33 1,956.93 248.82 -229.46 6,004,130.98 388,157.77 3.95 -336.81 MWD+IFR-AK-CAZ-SC(2) 2,156.67 37.58 311.57 2,072.37 2,031.97 285.77 -271.34 6,004,168.54 388,116.45 1.99 -391.52 MWD+IFR-AK-CAZ-SC(2) 2,248.99 39.21 311.75 2,144.73 2,104.33 323.88 -314.18 6,004,207.29 388,074.20 1.77 -447.74 MWD+IFR-AK-CAZ-SC(2) 2,342.34 40.70 311.26 2,216.28 2,175.88 363.60 -359.07 6,004,247.67 388,029.90 1.63 -506.48 MWD+IFR-AK-CAZ-SC(2) 2,435.53 41.39 312.38 2,286.57 2,246.17 404.41 -404.67 6,004,289.15 387,984.92 1.08 -566.51 MWD+IFR-AK-CAZ-SC(2) 2,527.12 41.45 312.78 2,355.25 2,314.85 445.40 -449.29 6,004,330.81 387,940.93 0.30 -626.11 MWD+IFR-AK-CAZ-SC(2) 2,617.66 41.12 312.60 2,423.28 2,382.88 485.91 -493.20 6,004,371.96 387,897.63 0.39 -684.88 MWD+IFR-AK-CAZ-SC(2) 2,685.35 40.77 313.74 2,474.41 2,434.01 516.26 -525.55 6,004,402.79 387,865.74 1.22 -728.59 MWD+IFR-AK-CAZ-SC(3) 2,722.66 41.16 312.84 2,502.59 2,462.19 533.03 -543.36 6,004,419.82 387,848.19 1.90 -752.69 MWD+IFR-AK-CAZ-SC(3) 2,817.70 40.25 312.74 2,574.63 2,534.23 575.13 -588.84 6,004,462.60 387,803.34 0.96 -813.69 MWD+IFR-AK-CAZ-SC(3) 2,910.04 40.55 312.20 2,644.95 2,604.55 615.54 -632.99 6,004,503.66 387,759.81 0.50 -872.53 MWD+IFR-AK-CAZ-SC(3) 3,002.47 41.58 312.27 2,714.64 2,674.24 656.35 -677.94 6,004,545.13 387,715.48 1.12 -932.18 MWD+IFR-AK-CAZ-SC(3) 3,094.93 41.28 312.14 2,783.97 2,743.57 697.45 -723.26 6,004,586.90 387,670.78 0.34 -992.28 MWD+IFR-AK-CAZ-SC(3) 3,187.35 41.19 311.84 2,853.47 2,813.07 738.21 -768.54 6,004,628.33 387,626.12 0.24 -1,052.08 MWD+IFR-AK-CAZ-SC(3) 3,280.44 40.82 313.11 2,923.72 2,883.32 779.45 -813.59 6,004,670.23 387,581.70 0.98 -1,112.13 MWD+IFR-AK-CAZ-SC(3) 3,370.65 41.14 313.98 2,991.82 2,951.42 820.21 -856.47 6,004,711.62 387,539.43 0.73 -1,170.48 MWD+IFR-AK-CAZ-SC(3) 3,464.91 40.74 313.92 3,063.02 3,022.62 863.07 -900.93 6,004,755.15 387,495.62 0.43 -1,231.48 MWD+IFR-AK-CAZ-SC(3) 3,557.72 41.75 313.97 3,132.81 3,092.41 905.54 -944.99 6,004,798.26 387,452.20 1.09 -1,291.90 MWD+IFR-AK-CAZ-SC(3) 3,650.10 41.33 313.76 3,201.95 3,161.55 947.99 -989.16 6,004,841.36 387,408.68 0.48 -1,352.39 MWD+IFR-AK-CAZ-SC(3) 3,743.20 40.57 313.20 3,272.27 3,231.87 989.97 -1,033.43 6,004,884.00 387,365.04 0.91 -1,412.56 MWD+IFR-AK-CAZ-SC(3) 3,834.99 40.75 312.57 3,341.90 3,301.50 1,030.67 -1,077.25 6,004,925.35 387,321.84 0.49 -1,471.44 MWD+IFR-AK-CAZ-SC(3) 3,924.86 40.41 311.79 3,410.16 3,369.76 1,069.93 -1,120.57 6,004,965.24 387,279.11 0.68 -1,528.86 MWD+I FR-AK-CAZ-SC(3) 4,020.52 41.23 313.29 3,482.55 3,442.15 1,112.21 -1,166.64 6,005,008.21 387,233.69 1.34 -1,590.35 MWD+IFR-AK-CAZ-SC(3) 4,113.36 40.31 313.27 3,552.86 3,512.46 1,153.77 -1,210.77 6,005,050.42 387,190.18 0.99 -1,650.11 MWD+IFR-AK-CAZ-SC(3) 4,204.97 41.21 314.07 3,622.25 3,581.85 1,195.07 -1,254.03 6,005,092.36 387,147.55 1.14 -1,709.13 MWD+IFR-AK-CAZ-SC(3) 4,299.01 41.58 314.28 3,692.80 3,652.40 1,238.41 -1,298.63 6,005,136.35 387,103.61 0.42 -1,770.57 MWD+IFR-AK-CAZ-SC(3) 3/14/2011 9:16:44AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.40ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +Et-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,389.42 41.28 314.42 3,760.58 3,720.18 1,280.23 -1,341.41 6,005,178.80 387,061.46 0.35 -1,829.72 MWD+IFR-AK-CAZ-SC(3) 4,484.24 41.19 314.02 3,831.89 3,791.49 1,323.82 -1,386.20 6,005,223.05 387,017.33 0.29 -1,891.48 MWD+I FR-AK-CAZ-SC(3) 4,574.62 40.75 313.64 3,900.13 3,859.73 1,364.85 -1,428.95 6,005,264.72 386,975.20 0.56 -1,949.99 MWD+I FR-AK-CAZ-SC(3) 4,669.21 40.59 313.68 3,971.87 3,931.47 1,407.41 -1,473.55 6,005,307.94 386,93125 0.17 -2,010.81 MWD+IFR-AK-CAZ-SC(3) 4,761.91 40.81 312.05 4,042.16 4,001.76 1,448.53 -1,517.85 6,005,349.71 386,887.57 1.17 -2,070.31 MWD+IFRAK-CAZ-SC(3) 4,855.04 41.02 311.00 4,112.53 4,072.13 1,488.96 -1,563.52 6,005,390.82 386,842.52 0.77 -2,130.09 MWD+IFRAK-CAZ-SC(3) 4,946.95 40.89 311.52 4,181.95 4,141.55 1,528.69 -1,608.81 6,005,431.22 386,797.84 0.40 -2,189.07 MWD+IFR-AK-CAZ-SC(3) 5,039.49 40.57 311.63 4,252.07 4,211.67 1,568.76 -1,653.98 6,005,471.95 386,753.27 0.35 -2,248.26 MWD+IFR-AK-CAZ-SC(3) 5,131.94 40.56 310.67 4,322.30 4,281.90 1,608.32 -1,699.25 6,005,512.18 386,708.61 0.68 -2,307.09 MWD+IFR-AK-CAZ-SC(3) 5,225.27 39.94 310.12 4,393.54 4,353.14 1,647.40 -1,745.17 6,005,551.94 386,663.27 0.77 -2,365.94 MWD+IFR-AK-CAZ-SC(3) 5,318.26 40.55 311.54 4,464.52 4,424.12 1,686.68 -1,790.62 6,005,591.89 386,618.42 1.18 -2,424.67 MWD+IFR-AK-CAZ-SC(3) 5,410.33 40.74 311.48 4,534.38 4,493.98 1,726.43 -1,835.53 6,005,632.30 386,574.11 0.21 -2,483.44 MWD+I FR-AK-CAZ-SC(3) 5,500.48 40.72 315.61 4,602.70 4,562.30 1,766.93 -1,878.15 6,005,673.44 386,532.11 2.99 -2,541.43 MWD+IFR-AK-CAZ-SC(3) 5,595.33 39.88 318.50 4,675.05 4,634.65 1,811.82 -1,919.94 6,005,718.94 386,490.99 2.16 -2,602.44 MWD+IFR-AK-CAZ-SC(3) 5,688.29 39.39 322.69 4,746.65 4,706.25 1,857.61 -1,957.58 6,005,765.28 386,454.05 2.92 -2,661.65 MWD+IFR-AK-CAZ-SC(3) 5,781.53 38.58 326.31 4,819.14 4,778.74 1,905.34 -1,991.64 6,005,813.51 386,420.71 2.59 -2,720.27 MWD+IFR-AK-CAZ-SC(3) 5,872.81 38.24 330.21 4,890.67 4,850.27 1,953.54 -2,021.47 6,005,862.15 386,391.61 2.68 -2,776.72 MWD+IFR-AK-CAZ-SC(3) 5,963.34 39.58 333.94 4,961.13 4,920.73 2,003.78 -2,048.06 6,005,912.77 386,365.77 2.98 -2,832.84 MWD+IFR-AK-CAZ-SC(3) 6,058.51 40.56 339.00 5,033.97 4,993.57 2,059.92 -2,072.48 6,005,969.27 386,342.20 3.57 -2,892.37 MWD+IFR-AK-CAZ-SC(3) III 6,150.81 39.71 345.70 5,104.57 5,064.17 2,116.53 -2,090.52 6,006,026.14 386,325.00 4.77 -2,948.44 MWD+IFR-AK-CAZ-SC(3) 6,241.20 40.03 349.45 5,173.96 5,133.56 2,173.10 -2,102.98 6,006,082.88 386,313.40 2.68 -3,001.12 MWD+IFR-AK-CAZ-SC(3) 6,337.05 38.72 353.48 5,248.06 5,207.66 2,233.20 -2,112.03 6,006,143.11 386,305.25 3.00 -3,054.56 MWD+IFR-AK-CAZ-SC(3) 6,429.41 38.19 358.60 5,320.41 5,280.01 2,290.46 -2,116.01 6,006,200.41 386,302.12 3.49 -3,102.68 MWD+IFR-AK-CAZ-SC(3) 6,522.60 36.59 3.96 5,394.46 5,354.06 2,346.98 -2,114.79 6,006,256.91 386,304.18 3.89 -3,147.10 MWD+IFR-AK-CAZ-SC(3) 6,615.05 36.80 11.30 5,468.63 5,428.23 2,401.65 -2,107.46 6,006,311.46 386,312.33 4.75 -3,186.34 MWD+IFR-AK-CAZ-SC(3) 6,707.50 35.48 16.07 5,543.30 5,502.90 2,454.60 -2,094.61 6,006,364.20 386,325.98 3.36 -3,220.89 MWD+IFR-AK-CAZ-SC(3) 6,752.78 34.15 18.55 5,580.48 5,540.08 2,479.28 -2,086.92 6,006,388.76 386,334.03 4.29 -3,235.98 MWD+IFR-AK-CAZ-SC(3) 6,800.57 32.75 21.12 5,620.36 5,579.96 2,504.05 -2,078.00 6,006,413.40 386,343.32 4.17 -3,250.40 MWD+IFR-AK-CAZ-SC(3) 6,848.36 31.56 23.44 5,660.82 5,620.42 2,527.59 -2,068.36 6,006,436.79 386,353.30 3.59 -3,263.39 MWD+IFR-AK-CAZ-SC(3) 6,894.01 29.74 26.53 5,700.09 5,659.69 2,548.68 -2,058.55 6,006,457.73 386,363.43 5.27 -3,274.34 MWD+IFR-AK-CAZ-SC(3) 6,939.18 27.99 30.47 5,739.65 5,699.25 2,567.85 -2,048.17 6,006,476.73 386,374.09 5.72 -3,283.39 MWD+IFR-AK-CAZ-SC(3) 6,986.57 26.62 33.67 5,781.76 5,741.36 2,586.27 -2,036.65 6,006,494.98 386,385.89 4.24 -3,291.17 MWD+IFR-AK-CAZ-SC(3) 7,031.32 26.42 37.42 5,821.80 5,781.40 2,602.52 -2,025.04 6,006,511.06 386,397.74 3.77 -3,297.16 MWD+IFR-AK-CAZ-SC(3) 7,078.77 26.96 41.94 5,864.20 5,823.80 2,618.91 -2,011.43 6,006,527.24 386,411.59 4.43 -3,302.06 MWD+IFR-AK-CAZ-SC(3) 7,124.58 27.56 47.51 5,904.93 5,864.53 2,633.79 -1,996.67 6,006,541.90 386,426.57 5.72 -3,305.07 MWD+IFR-AK-CAZ-SC(3) 7,171.54 28.45 52.98 5,946.40 5,906.00 2,647.87 -1,979.73 6,006,555.72 386,443.72 5.79 -3,306.11 MW D+I FR-AK-CAZ-SC(3) 7,214.16 28.09 57.10 5,983.94 5,943.54 2,659.43 -1,963.20 6,006,567.03 386,460.42 4.65 -3,305.40 MWD+IFR-AK-CAZ-SC(3) 7,263.59 28.45 62.25 6,027.48 5,987.08 2,671.24 -1,943.00 6,006,578.53 386,480.79 4.99 -3,302.67 MWD+IFR-AK-CAZ-SC(3) 7,308.10 28.96 67.33 6,066.53 6,026.13 2,680.33 -1,923.67 6,006,587.33 386,500.25 5.60 -3,298.30 MWD+IFR-AK-CAZ-SC(3) 7,352.31 30.06 71.38 6,105.00 6,064.60 2,687.99 -1,903.30 6,006,594.69 386,520.73 5.15 -3,292.16 MWD+IFR-AK-CAZ-SC(3) 3/14/2011 9:16:44AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.40ft(D141) Site: CD3 Fiord Pad I0D Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section I (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,400.19 30.75 76.15 6,146.30 6,105.90 2,69475 -1,880.05 6,006,601.10 386,544.08 5.24 -3,283.56 MWD+IFR-AK-CAZ-SC(3) 7,442.28 32.23 80.14 6,182.20 6,141.80 2,699.25 -1,858.54 6,006,605.27 386,565.65 6.07 -3,274.21 MWD+IFR-AK-CAZ-SC(3) 7,482.95 33.28 83.41 6,216.40 6,176.00 2,702.39 -1,836.77 6,006,608.09 386,587.47 5.06 -3,263.62 MWD+IFR-AK-CAZ-SC(3) 7,532.78 35.22 87.57 6,257.60 6,217.20 2,704.56 -1,808.83 6,006,609.85 386,615.44 6.10 -3,248.54 MWD+IFR-AK-CAZ-SC(3) 7,588.05 35.94 90.53 6,302.55 6,262.15 2,705.09 -1,776.68 6,006,609.89 386,647.58 3.38 -3,229.61 MWD+IFR-AK-CAZ-SC(3) 7,633.39 36.72 94.13 6,339.08 6,298.68 2,703.99 -1,749.85 6,006,608.39 386,674.39 5.01 -3,212.59 MWD+IFR-AK-CAZ-SC(3) 7,680.13 38.36 96.95 6,376.15 6,335.75 2,701.23 -1,721.51 6,006,605.21 386,702.68 5.08 -3,193.33 MWD+IFR-AK-CAZ-SC(3) 7,726.49 40.45 99.40 6,411.97 6,371.57 2,697.03 -1,692.39 6,006,600.57 386,731.73 5.62 -3,172.45 MWD+IFR-AK-CAZ-SC(3) 7,774.69 41.76 102.30 6,448.29 6,407.89 2,691.06 -1,661.28 6,006,594.14 386,762.75 4.80 -3,148.96 MWD+IFR-AK-CAZ-SC(3) 7,819.56 42.74 105.00 6,481.50 6,441.10 2,683.93 -1,631.97 6,006,586.58 386,791.95 4.60 -3,125.63 MWD+IFR-AK-CAZ-SC(3) 7,863.14 44.33 107.53 6,513.10 6,472.70 2,675.52 -1,603.16 6,006,577.73 386,820.62 5.41 -3,101.57 MWD+IFR-AK-CAZ-SC(3) 7,912.48 45.57 111.15 6,548.02 6,507.62 2,663.97 -1,570.29 6,006,565.69 386,853.32 5.76 -3,072.56 MWD+IFR-AK-CAZ-SC(3) 7,958.09 46.96 112.84 6,579.56 6,539.16 2,651.62 -1,539.74 6,006,552.89 386,883.68 4.06 -3,044.31 MWD+IFR-AK-CAZ-SC(3) 8,002.50 48.80 113.36 6,609.34 6,568.94 2,638.69 -1,509.44 6,006,539.51 386,913.78 4.23 -3,015.76 MWD+IFR-AK-CAZ-SC(3) 8,047.47 51.10 114.22 6,638.27 6,597.87 2,624.81 -1,477.94 6,006,525.16 386,945.06 5.32 -2,985.71 MWD+IFR-AK-CAZ-SC(3) 8,091.82 53.33 114.51 6,665.45 6,625.05 2,610.35 -1,446.02 6,006,510.22 386,976.76 5.05 -2,954.95 MWD+IFR-AK-CAZ-SC(3) 8,143.19 55.24 116.10 6,695.43 6,655.03 2,592.51 -1,408.32 6,006,491.83 387,014.19 4.49 -2,918.02 MWD+IFR-AK-CAZ-SC(3) 8,191.48 57.12 118.68 6,722.31 6,681.91 2,574.05 -1,372.71 6,006,472.84 387,049.52 5.90 -2,881.84 MWD+IFR-AK-CAZ-SC(3) 8,236.04 58.95 120.37 6,745.90 6,705.50 2,555.42 -1,339.82 6,006,453.72 387,082.12 5.22 -2,847.17 MWD+IFR-AK-CAZ-SC(3) 8,283.38 60.59 122.19 6,769.74 6,729.34 2,534.18 -1,304.87 6,006,431.96 387,116.75 4.80 -2,809.17 MWD+IFR-AK-CAZ-SC(3) 8,331.52 62.20 123.18 6,792.78 6,752.38 2,511.35 -1,269.30 6,006,408.61 387,151.97 3.80 -2,769.54 MWD+IFR-AK-CAZ-SC(3) 8,374.65 63.59 124.19 6,812.44 6,772.04 2,490.06 -1,237.36 6,006,386.84 387,183.59 3.84 -2,733.31 MWD+IFR-AK-CAZ-SC(3) 8,422.26 65.20 125.28 6,833.01 6,792.61 2,465.59 -1,202.08 6,006,361.85 387,218.49 3.96 -2,692.54 MWD+IFR-AK-CAZ-SC(3) 8,469.10 66.11 125.57 6,852.32 6,811.92 2,440.86 -1,167.30 6,006,336.60 387,252.89 2.02 -2,651.86 MWD+IFR-AK-CAZ-SC(3) 8,515.87 67.55 126.70 6,870.72 6,830.32 2,415.50 -1,132.58 6,006,310.73 387,287.23 3.80 -2,610.71 MWD+IFR-AK-CAZ-SC(3) 8,561.43 69.57 128.15 6,887.38 6,846.98 2,389.73 -1,098.91 6,006,284.46 387,320.51 5.33 -2,569.86 MWD+IFR-AK-CAZ-SC(3) 8,607.81 72.25 129.63 6,902.54 6,862.14 2,362.21 -1,064.80 6,006,256.44 387,354.20 6.52 -2,527.36 MW D+I FR-AK-CAZ-SC(3) 8,651.50 75.22 130.66 6,914.78 6,874.38 2,335.17 -1,032.74 6,006,228.93 387,385.84 7.16 -2,486.47 MW D+I FR-AK-CAZ-SC(3) 8,700.79 78.01 130.67 6,926.19 6,885.79 2,303.93 -996.38 6,006,197.14 387,421.74 5.66 -2,439.63 MWD+IFR-AK-CAZ-SC(3) 8,742.81 79.64 131.42 6,934.33 6,893.93 2,276.86 -965.29 6,006,169.62 387,452.41 4.26 -2,399.31 MWD+IFR-AK-CAZ-SC(3) 8,791.53 81.69 132.05 6,942.23 6,901.83 2,244.86 -929.41 6,006,137.09 387,487.80 4.40 -2,352.16 MWD+IFR-AK-CAZ-SC(3) 8,840.63 82.57 133.81 6,948.96 6,908.56 2,211.73 -893.81 6,006,103.43 387,522.91 3.98 -2,304.27 MWD+IFR-AK-CAZ-SC(3) 8,889.47 83.34 131.95 6,954.95 6,914.55 2,178.75 -858.29 6,006,069.93 387,557.93 4.10 -2,256.56 MWD+IFR-AK-CAZ-SC(4) 8,982.91 85.56 133.83 6,963.99 6,923.59 2,115.46 -790.16 6,006,005.63 387,625.10 3.11 -2,165.01 MWD+IFR-AK-CAZ-SC(4) 9,079.22 88.53 137.72 6,968.95 6,928.55 2,046.55 -723.10 6,005,935.73 387,691.11 5.08 -2,069.62 MWD+IFR-AK-CAZ-SC(4) 9,127.27 88.97 139.62 6,970.00 6,929.60 2,010.48 -691.37 6,005,899.20 387,722.29 4.06 -2,021.72 MWD+IFR-AK-CAZ-SC(4) 9,172.14 89.33 140.20 6,970.67 6,930.27 1,976.16 -662.48 6,005,864.45 387,750.66 1.52 -1,976.92 MWD+IFR-AK-CAZ-SC(4) 9,225.47 89.27 140.92 6,971.32 6,930.92 1,934.98 -628.61 6,005,822.77 387,783.92 1.35 -1,923.65 MWD+IFR-AK-CAZ-SC(4) 9,267.58 89.15 140.37 6,971.90 6,931.50 1,902.42 -601.91 6,005,789.82 387,810.13 1.34 -1,881.58 MWD+IFR-AK-CAZ-SC(4) 9,361.55 88.66 139.93 6,973.69 6,933.29 1,830.29 -541.70 6,005,716.80 387,869.24 0.70 -1,787.74 MWD+IFR-AK-CAZ-SC(4) 3/14/2011 9:16:44AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.40ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) ( ) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,454.91 88.66 140.63 6,975.88 6,935.48 1,758.50 -482.06 6,005,644.13 387,927.80 0.75 -1,694.51 MWD+IFR-AK-CAZ-SC(4) 9,548.70 88.72 141.11 6,978.02 6,937.62 1,685.76 -422.89 6,005,570.53 387,985.87 0.52 -1,600.81 MWD+IFR-AK-CAZ-SC(4) 9,644.70 88.22 138.80 6,980.58 6,940.18 1,612.30 -361.15 6,005,496.16 388,046.50 2.46 -1,504.99 MWD+IFR-AK-CAZ-SC(4) 9,738.07 87.59 137.82 6,984.00 6,943.60 1,542.63 -299.09 6,005,425.57 388,107.50 1.25 -1,411.99 MWD+IFR-AK-CAZ-SC(4) 9,831.54 87.77 138.06 6,987.78 6,947.38 1,473.29 -236.52 6,005,355.31 388,169.02 0.32 -1,318.96 MWD+IFR-AK-CAZ-SC(4) 9,925.95 88.64 140.99 6,990.74 6,950.34 1,401.51 -175.28 6,005,282.63 388,229.18 3.24 -1,224.78 MWD+IFR-AK-CAZ-SC(4) 10,021.10 89.50 146.19 6,992.28 6,951.88 1,324.98 -118.83 6,005,205.26 388,284.47 5.54 -1,129.69 MWD+IFR-AK-CAZ-SC(4) 10,068.18 90.00 148.18 6,992.49 6,952.09 1,285.41 -93.32 6,005,165.33 388,309.39 4.36 -1,082.73 MWD+IFR-AK-CAZ-SC(4) 10,113.29 90.67 148.47 6,992.23 6,951.83 1,247.02 -69.63 6,005,126.59 388,332.50 1.62 -1,037.82 MWD+IFR-AK-CAZ-SC(4) 10,209.69 89.81 148.64 6,991.82 6,951.42 1,164.78 -19.34 6,005,043.61 388,381.55 0.91 -941.87 MWD+IFR-AK-CAZ-SC(4) 10,303.16 89.87 150.13 6,992.08 6,951.68 1,084.34 28.26 6,004,962.48 388,427.93 1.60 -848.99 MWD+IFR-AK-CAZ-SC(4) 10,394.95 90.55 148.47 6,991.75 6,951.35 1,005.42 75.12 6,004,882.87 388,473.61 1.95 -757.76 MWD+IFR-AK-CAZ-SC(4) 10,489.10 89.13 145.72 6,992.01 6,951.61 926.38 126.26 6,004,803.09 388,523.55 3.29 -663.86 MWD+IFR-AK-CAZ-SC(4) 10,583.52 89.81 144.31 6,992.88 6,952.48 849.03 180.39 6,004,724.94 388,576.52 1.66 -569.50 MWD+IFR-AK-CAZ-SC(4) 10,679.27 89.93 143.35 6,993.10 6,952.70 771.74 236.90 6,004,646.82 388,631.86 1.01 -473.76 MWD+IFR-AK-CAZ-SC(4) 10,773.00 89.75 143.32 6,993.36 6,952.96 696.55 292.87 6,004,570.81 388,686.70 0.19 -380.04 MWD+IFR-AK-CAZ-SC(4) 10,866.28 89.19 142.63 6,994.23 6,953.83 622.08 349.04 6,004,495.52 388,741.74 0.95 -286.76 MWD+IFR-AK-CAZ-SC(4) 10,960.36 89.63 143.04 6,995.19 6,954.79 547.12 405.87 6,004,419.71 388,797.44 0.64 -192.69 MWD+IFR-AK-CAZ-SC(4) 11,053.40 89.01 144.27 6,996.30 6,955.90 472.18 461.00 6,004,343.97 388,851.44 1.48 -99.66 MWD+IFR-AK-CAZ-SC(4) 11,148.27 90.12 142.80 6,997.02 6,956.62 395.89 517.38 6,004,266.85 388,906.67 1.94 -4.80 MWD+IFR-AK-CAZ-SC(4) 11,242.49 89.69 142.80 6,997.18 6,956.78 320.84 574.35 6,004,190.97 388,962.50 0.46 89.42 MWD+IFR-AK-CAZ-SC(4) 11,336.04 89.56 144.35 6,997.79 6,957.39 245.57 629.89 6,004,114.88 389,016.91 1.66 182.96 MWD+IFR-AK-CAZ-SC(4) 11,430.28 89.75 144.64 6,998.36 6,957.96 168.86 684.62 6,004,037.36 389,070.48 0.37 277.16 MWD+IFR-AK-CAZ-SC(4) 11,523.79 89.75 145.09 6,998.76 6,958.36 92.39 738.44 6,003,960.10 389,123.14 0.48 370.62 MWD+IFR-AK-CAZ-SC(4) 11,619.06 89.13 146.15 6,999.69 6,959.29 13.76 792.23 6,003,880.69 389,175.75 1.29 465.79 MWD+IFR-AK-CAZ-SC(4) 11,713.05 89.32 147.44 7,000.97 6,960.57 -64.87 843.70 6,003,801.30 389,226.03 1.39 559.56 MWD+IFR-AK-CAZ-SC(4) 11,807.62 89.69 148.55 7,001.78 6,961.38 -145.06 893.82 6,003,720.38 389,274.94 1.24 653.76 MWD+IFR-AK-CAZ-SC(4) 11,901.71 89.93 148.96 7,002.09 6,961.69 -225.50 942.62 6,003,639.22 389,322.53 0.50 747.38 MWD+IFR-AK-CAZ-SC(4) 11,994.68 89.69 146.80 7,002.40 6,962.00 -304.24 992.05 6,003,559.76 389,370.77 2.34 840.01 MWD+IFR-AK-CAZ-SC(4) 12,089.04 89.19 143.12 7,003.33 6,962.93 -381.48 1,046.21 6,003,481.73 389,423.77 3.94 934.29 MWD+IFR-AK-CAZ-SC(4) 12,183.61 88.64 141.69 7,005.12 6,964.72 -456.40 1,103.90 6,003,405.96 389,480.32 1.62 1,028.84 MWD+IFR-AK-CAZ-SC(4) 12,275.65 89.19 141.58 7,006.86 6,966.46 -528.55 1,161.01 6,003,332.97 389,536.35 0.61 1,120.83 MWD+IFR-AK-CAZ-SC(4) 12,371.00 89.81 142.39 7,007.69 6,967.29 -603.67 1,219.73 6,003,256.99 389,593.94 1.07 1,216.16 MWD+IFR-AK-CAZ-SC(4) 12,464.52 89.19 142.19 7,008.51 6,968.11 -677.65 1,276.93 6,003,182.17 389,650.02 0.70 1,309.67 MWD+IFR-AK-CAZ-SC(4) 12,558.78 88.82 140.15 7,010.14 6,969.74 -751.06 1,336.02 6,003,107.89 389,708.00 2.20 1,403.86 MWD+IFR-AK-CAZ-SC(4) 12,652.35 88.95 141.39 7,011.97 6,971.57 -823.53 1,395.19 6,003,034.55 389,766.07 1.33 1,497.34 MWD+IFR-AK-CAZ-SC(4) 12,745.58 89.19 142.82 7,013.48 6,973.08 -897.09 1,452.44 6,002,960.15 389,822.21 1.56 1,590.55 MWD+IFR-AK-CAZ-SC(4) 12,840.44 89.87 143.08 7,014.26 6,973.86 -972.79 1,509.59 6,002,883.60 389,878.22 0.77 1,685.40 MWD+IFR-AK-CAZ-SC(4) 12,935.41 89.26 141.18 7,014.98 6,974.58 -1,047.76 1,567.89 6,002,807.78 389,935.38 2.10 1,780.35 MWD+IFR-AK-CAZ-SC(4) 13,029.27 88.33 141.13 7,016.95 6,976.55 -1,120.84 1,626.75 6,002,733.83 389,993.14 0.99 1,874.14 MWD+IFR-AK-CAZ-SC(4) 3/14/2011 9:16:44AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-199 Project: Western North Slope TVD Reference: Rig:CD3-199 @ 40.4011(D141) Site: CD3 Fiord Pad MD Reference: Rig:CD3-199 @ 40.40ft(D141) Well: CD3-199 North Reference: True Wellbore: CD3-199 Survey Calculation Method: Minimum Curvature Design: CD3-199 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S -i-IE/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 13,123.53 88.21 142.34 7,019.80 6,979.40 -1,194.82 1,685.09 6,002,659.00 390,050.37 1.29 1,968.34 MWD+IFR-AK-CAZ-SC(4) 13,217.81 88.27 145.12 7,022.69 6,982.29 -1,270.78 1,740.84 6,002,582.21 390,104.96 2.95 2,062.56 MWD+IFR-AK-CAZ-SC(4) 13,311.85 88.27 146.81 7,025.53 6,985.13 -1,348.68 1,793.45 6,002,503.55 390,156.40 1.80 2,156.42 MWD+IFR-AK-CAZ-SC(4) 13,405.91 88.45 146.35 7,028.22 6,987.82 -1,427.15 1,845.23 6,002,424.32 390,207.00 0.52 2,250.26 MWD+IFR-AK-CAZ-SC(4) 13,500.27 89.75 148.21 7,029.71 6,989.31 -1,506.52 1,896.22 6,002,344.20 390,256.79 2.40 2,344.34 MWD+IFR-AK-CAZ-SC(4) 13,592.63 90.92 149.24 7,029.17 6,988.77 -1,585.46 1,944.17 6,002,264.56 390,303.55 1.69 2,436.23 MWD+IFR-AK-CAZ-SC(4) 13,686.55 90.55 149.37 7,027.96 6,987.56 -1,666.21 1,992.11 6,002,183.10 390,350.27 0.42 2,529.58 MWD+IFR-AK-CAZ-SC(4) 13,781.05 91.05 148.11 7,026.64 6,986.24 -1,746.98 2,041.14 6,002,101.62 390,398.09 1.43 2,623.59 MWD+IFR-AK-CAZ-SC(4) 13,875.51 90.43 145.77 7,025.42 6,985.02 -1,826.14 2,092.66 6,002,021.71 390,448.42 2.56 2,717.82 MWD+IFR-AK-CAZ-SC(4) 13,969.50 90.68 146.39 7,024.51 6,984.11 -1,904.13 2,145.11 6,001,942.95 390,499.69 0.71 2,811.67 MWD+IFR-AK-CAZ-SC(4) 14,064.57 90.92 144.92 7,023.18 6,982.78 -1,982.61 2,198.74 6,001,863.68 390,552.13 1.57 2,906.62 MWD+IFR-AK-CAZ-SC(4) 14,157.46 89.87 142.52 7,022.54 6,982.14 -2,057.49 2,253.70 6,001,788.00 390,605.96 2.82 2,999.49 MWD+IFR-AK-CAZ-SC(4) 14,251.58 88.39 140.99 7,023.97 6,983.57 -2,131.39 2,311.95 6,001,713.23 390,663.10 2.26 3,093.57 MWD+IFR-AK-CAZ-SC(4) 14,344.90 89.19 142.56 7,025.94 6,985.54 -2,204.69 2,369.68 6,001,639.09 390,719.72 1.89 3,186.85 MWD+IFR-AK-CAZ-SC(4) 14,438.64 89.69 143.69 7,026.86 6,986.46 -2,279.67 2,425.93 6,001,563.29 390,774.83 1.32 3,280.58 MWD+IFR-AK-CAZ-SC(4) 14,535.08 89.38 144.91 7,027.64 6,987.24 -2,357.98 2,482.20 6,001,484.15 390,829.92 1.31 3,376.99 MWD+IFR-AK-CAZ-SC(4) 14,547.58 89.50 144.63 7,027.77 6,987.37 -2,368.19 2,489.41 6,001,473.83 390,836.98 2.44 3,389.49 MWD+IFR-AK-CAZ-SC(4) 14,646.44 90.98 146.40 7,027.35 6,986.95 -2,449.67 2,545.38 6,001,391.53 390,891.72 2.33 3,488.24 MWD+IFR-AK-CAZ-SC(4) 14,738.37 91.05 146.55 7,025.72 6,985.32 -2,526.30 2,596.14 6,001,314.16 390,941.33 0.18 3,579.99 MWD+IFR-AK-CAZ-SC(4) 14,833.72 91.11 144.02 7,023.93 6,983.53 -2,604.66 2,650.43 6,001,235.01 390,994.43 2.65 3,675.24 MWD+IFR-AK-CAZ-SC(4) 14,928.18 90.55 143.43 7,022.56 6,982.16 -2,680.80 2,706.31 6,001,158.04 391,049.17 0.86 3,769.68 MWD+IFR-AK-CAZ-SC(4) 15,022.10 90.24 144.10 7,021.91 6,981.51 -2,756.55 2,761.83 6,001,081.47 391,103.54 0.79 3,863.59 MWD+IFR-AK-CAZ-SC(4) 15,117.55 91.31 143.14 7,020.62 6,980.22 -2,833.39 2,818.44 6,001,003.80 391,158.99 1.51 3,959.02 MWD+IFR-AK-CAZ-SC(4) 15,210.29 90.68 140.90 7,019.01 6,978.61 -2,906.47 2,875.49 6,000,929.88 391,214.94 2.51 4,051.73 MWD+IFR-AK-CAZ-SC(4) 15,304.88 90.49 141.66 7,018.04 6,977.64 -2,980.27 2,934.66 6,000,855.22 391,272.99 0.83 4,146.27 MWD+IFR-AK-CAZ-SC(4) 15,398.78 91.42 143.24 7,016.48 6,976.08 -3,054.70 2,991.88 6,000,779.94 391,329.08 1.95 4,240.15 MWD+IFR-AK-CAZ-SC(4) 15,492.84 90.49 142.99 7,014.91 6,974.51 -3,129.92 3,048.32 6,000,703.89 391,384.39 1.02 4,334.20 MWD+IFR-AK-CAZ-SC(4) 15,584.92 91.66 143.41 7,013.18 6,972.78 -3,203.64 3,103.47 6,000,629.37 391,438.43 1.35 4,426.26 MWD+IFR-AK-CAZ-SC(4) 15,678.89 91.91 142.53 7,010.25 6,969.85 -3,278.62 3,160.03 6,000,553.55 391,493.86 0.97 4,520.18 MWD+IFR-AK-CAZ-SC(4) 15,742.00 • 91.91 142.53 7,008.15 • 6,967.75 -3,328.68 3,198.41 6,000,502.93 391,531.48 0.00 4,583.25 PROJECTED to TD 3/14/2011 9:16:44AM Page 7 COMPASS 2003.16 Build 69 \ WNS CD3-199 ConocoPhillips i wen Att tes -__ Max Angle&MD _TD Alaska)Inc Wellbore APW WI Field Name Well Status Incl(") MD(ftKB) Ad Btm(ftKB) 501032063500__ FIORD NECHELIK PROD 91.91 15,678.89 15,742.0 Comment 1H2S(ppm) 'Date Annotation End Date KBGrd(ft) Rig Release Date wgttcchotai_119V9nft/v Cg3-aq9 321/2all --... SSSV-.I RDP Last WO: 28 00 3/11/2011 '- - Schgmets_,gn,M3it._-- Annotation Depth(ftKB) /End Date 'Annotation 'Last Mod...End Date 1_ast lag Rev Reason: Imosbor 3/21/2011 HANGER,21 4i ,'1•ti I_ I__- _.._._. Casing Strings ' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt...'String...String Top Thrd 117 CONDUCTOR 16 15.250 31.0 114.0 114.0 62.50 H-40 Welded . - L - Caning Caning Description Sting 0... String ID._Top MKe) Set Depth(f_._SN Depth(ND).-String Wt...String...Sting Top That SURFACE 95/8 8.835 26.5 2,662.8 2,457.3 40.00 L-80 BTC-m ',ir Casing Description ption String0._ ._String ID Top(N (f_ KB) Set Depth .Set Depth(TVD)...String Wt...String._String Top Thrd CONDUCTOR._ J ' INTERMEDIATE 7 6.276 25.2 8,870.0 6,952.5 26.00 L-80 BTC-m 31-114 --__ Casing Description Sting 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt...String...String Top Thrd_ LINER 31/2 2.992 8,700.9 15,742.0 9.30 L-80 SLHT SAFETY VLV, WOW.- Liner Details.. --- 2.057 Top Depth (TVD) Top Inel Nomi... 6I Top(ftKB) (flKB) (°) 166.DesoriptbCommentn Comment -__ ID(in) 8,700.9 6,925.5 77.88 PACKER "HRD"ZXP Liner Top Packer 4.360 SURFACE, 26-2,663 8,720.7 6,930.0 78.71 NIPPLE "RS"Packoti Nipple 4.260 8,723.5 6,930.6 78.83 HANGER Flex-Lock Liner Hanger 4.360 GAS LIFT. 3,968 8,734.8 6,932.8 79.30 SBE Seal Bore Extension 4.000 8,753.5 6,936.2 80.09 XO BUSHING Cross Over Bushing - -- -------_---- 2.937 8,890.5 6,952.3 82.71 Swell Packer Water Activated Assembly,TAM Swell Packer -- 2.960 8,968.6 6,962.8 85.12 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 GAS LIFT, • 9,419.0 6,975.0 88.66 FRAC PORT Ball Actuated Sleeve(2.000") _ -- _----- 2.000 6,769 ---- --- 9,832.0 6,987.1 87.79 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 10,313.2 6,994.3 91.78 FRAC PORT Ball Actuated Sleeve(1.875") --- 1.875 GASIIA '_ iirl!-, 10,760.9 6,993.3 89.82 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 8 11,303.3 6,997.5 89.49 FRAC PORT Ball Actuated Sleeve(1.750") 1.750 NIPPLE,8,516- Y J: 11,874.7 7,002.1 90.00 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 12,108.0 7,002.7 88.19 FRAC PORT Ball Actuated Sleeve(1-625") 1.625 LOCATOR, ,.,1111r,r.....' 12,340.1 7,007.5 89.61 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 8,711 12,848.9 7,014.3 89.82 FRAC PORT Ball Actuated Sleeve(1.500") 1.500 I. 13,390.7 7,027.8 88.24 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 13,904.1 7,025.1 90.51 FRAC PORT Ball Actuated Sleeve(1.375") 1.375 SEAL ASSY,_ .l 8,743 11W4 14,445.3 7,025.3 88.52 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 SEAL Assv,_______ 14,959.8 7,021.4 89.54 FRAC PORT Ball Actuated Sleeve(1.25") 1.250 8,751 „,:e. > 15,466.4 7,015.3 90.75 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 Tubing Strings �, Tubing Description /String 0... String ID Top(ftKB) Set Depth(f...Set Depth(WD) String Wt..-/String...Siting Top Thrd u ` /TUBING __.j 31/2 (_2992 I 213 � 8753.1 6,936.1 l 930IIS L-80 EUE-8rd-mod._ )ITERMEDIATE, Completion Details 258,870 Top Depth (TVD) Top Incl Nomi... --. - Tap{NKB) (ftKB) (1 Nem Description Comment ID(in) 21.3 21.3 -0.03 HANGER FMC 4-1/2"x 11"tubing hanger(10.85"OD) 4.500 130.2 130.2 0.47 XO-Reducing Crossover 4-1/2"12.6 ppf L-80 IBT-m box x 3-1/2"9.3 ppf L-80 EUE-m 2.992 pin 2,056.7 1,992.1 35.49 SAFETY VLV 3-1/2"Camco TRMAXX-5E w/2.812""X"profile,1/4"single control line 2.812 - 8,516.2 6,869.7 66.96 NIPPLE HES"XN"nipple(2.813"profile 2/2 75"No-go)w/RHC plug installed 2.813 8,711.5 6,928.0 78.32 LOCAl OR Baker 80-40 GBH locator 2.970 8,743.1 6,934.4 79.65 SEAL ASSY 80-40 Bonded Seal assembly 3.000 8,751.0 6,935.8 79.991 SEAL ASSY 80-40 Seal assembly w/1/2 mule shoe 3.000 Notes:General&Safety • End Date Annotation 1111 3/21/2011 f NOTE:VIEW SCHEMATIC wlAlaska Schematic9.0 a ill U_ I - =- Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch Sian TRO Run Stn Top MKS) (R) (1 Make Modal Onl Sary Type Type lin) (Pei Run Date Com... 1 3,907.8 3,397.1 40.26 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/10/2011 PI 2 6,769.0 5,594.0 33.54 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/10/2011 3 8,372.8 6,811.6 63.53 CAMCO KBMG 1 GAS LIFT SOV INT 0.000 0.0 3/10/2011 NI M_ TO,15,742 LNER, 8,701-15,742'' ConocoPhillips Time Log & Summary We,N,ew Web Repm7rng Report Well Name: CD3-199 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 2/7/2011 12:00:00 PM Rig Release: 3/11/2011 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/07/2011 24 hr Summary. Released Doyon 141 F/CD3-125 2/6/2011 @ 24:00 Hrs. Rig down, Prep for move to CD3-199, rig up, accept rig at 1200 hrs 2/7/2011, nipple up,pick up 8 stands of 5"HWDP and rack in derrick, PU/MU BHA, clean out conductor f/106'to 114',drill f/114'to 200'. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P PJSM, Rig down service lines,Air, Water, Steam and electrical connections for rig move to CD3-199. 01:00 03:00 2.00 0 0 MIRU MOVE MOB P Move and stage rockwasher, boiler, motor, pump,and pit complexes. 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Move sub structure off CD3-125 spot over well CD3-199 05:00 08:30 3.50 0 0 MIRU MOVE MOB P Spot pit, pump,motor, boiler and rockwasher complexes 08:30 09:30 1.00 0 0 MIRU MOVE MOB P Spot pipe sheds. 09:30 11:00 1.50 0 0 MIRU MOVE RURD P Hook up all service lines. Electrical, water,air and steam to complexes and sub. 11:00 12:00 1.00 0 0 MIRU MOVE RURD P Complete rig acceptance checklist. Rig accepted @ 12:00 hrs. 12:00 16:30 4.50 0 0 SURFA( DRILL NUND P Nipple up surface stack,Sim-ops. Take on spud mud, Load pipeshed with 5"HWDP, Drill collars, Mud motor. (MWD tools were left in shed during move to expedite pick up of BHA.) 16:30 19:00 2.50 0 0 SURFA( DRILL PULD P Rig up floor to pick up 5"HWDP, Pick up 24 joints(8 Stands)5" HWDP and rack in derrick. 19:00 21:45 2.75 0 0 SURFA( DRILL PULD P Pick up conductor clean out assembly, Bit, Motor, Stabilizer, Float sub, UBHO,Crossover sub. UBHO oriented to motor) 21:45 22:00 0.25 0 0 SURFA( DRILL REAM P Wash and ream,clean out conductor F/106'MD-T/114'MD With 120 vis, Switched over to 300 vis mud at 150' MD 22:00 00:00 2.00 0 200 SURFA( DRILL DDRL P Drill F/114'MD-T/200'MD,TVD- • 200' Drilling parameters,40 rpm, 500 gpm, bit wt 3-5k, Pressure off 600 psi, Pressure on 650 psi,Torque off 0 torque on 1-2k, Flow percentage 70%, Up,down and rotating weights 45k.ADT 1.19 ART 1.19 AST 1.19. Total bit hrs-1.19. 02/08/2011 Drill 12-1/4"surface hole F/200'T/228'allowing length to P/U BHA#2. POOH to 40', P/U and M/U BHA#2 (DM collar, HCIM collar, POS Pulser, UBHO). Upload MWD,M/U remainder BHA#2(NMFDC,Jars, and HWDP).Shallow pulse test MWD. Directional drill 12-1/4"hole F/228'T/1458'MD. Page 1 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 200 228 SURFA( DRILL DDRL P PJSM, Drill 12-1/4"F/200'MD T/ 228'MD allowing jars to be placed below rotary once picked up. Drilling parameters:40 rpm,WOB 2-5k lbs, 450 gpm,torque off/on 0k/1-2k ft-lbs, and pressure off/on 650/670 psi. P/U 47k lbs,S/O 47k lbs, ROT 47k lbs. ADT 0.69,ART 0.69,AST 0.0 and total bit hours-1.88. Flow percentage 70%, 00:30 01:00 0.50 228 40 SURFA( DRILL TRIP P POOH with cleanout assembly F/ 228'T/40'to P/U remainder of 'surface BHA(MWD tools). 01:00 02:00 1.00 40 78 SURFA( DRILL PULD P P/U and M/U partial of BHA#2(DM collar, HCIM collar, POS Pulser, UBHO). 02:00 02:30 0.50 58 58 SURFA( DRILL OTHR P Upload MWD at HCIM collar. 02:30 02:45 0.25 228 228 SURFA( DRILL PULD P P/U and M/U remainder of BHA#2 (NMFDC,Jars,and HWDP). 02:45 03:00 0.25 228 228 SURFA( DRILL DHEQ P Shallow pulse test 500 gpm w/900 psi. 03:00 12:00 9.00 228 719 SURFA( DRILL DDRL P Directionally drill 12-1/4"F/228'MD T/719'MD. Drilling parameters: 50 rpm,WOB 20k lbs,450 gpm,torque off/on 1k/3k ft-lbs,and pressure off/on 1250/1340 psi. P/U 75k lbs, S/O 75k lbs, ROT 75k lbs. ADT 3.34,ART 2.29,AST 1.05,total bit hours-5.22 and total jar hours- 31.61. 12:00 00:00 12.00 719 1,458 SURFA( DRILL DDRL P Directionally drill 12-1/4"F/719'MD T/1458'MD. Drilling parameters: 50 rpm,WOB 20k lbs,450 gpm,torque off/on 1k/3k ft-lbs,and pressure off/on 1250/1340 psi. P/U 93k lbs, S/O 89k lbs, ROT 50k lbs. ADT 5.57,ART 2.45,AST 3.12,total bit hours-10.79 and total jar hours- 37.18. Halliburton Gyro placed on standby at 20:00 hours and released at 22:00. Offloaded first bulk load of Arctic Set 3 cement at 23:00 hours. 02/09/2011 Continue drilling 12-1/4"surface hole from 1458'MD to TD of 2673'MD/2465'TVD. Circulate 2 B/U and BROOH to HWDP at 906'MD. TIN on elevators to 2667'MD and wash down last 6'to TD on single of drill pipe,work tight spot at 931'MD. Condition and circulate mud from 9.6 ppg to 10.0 ppg. Page 2 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 1,458 2,507 SURFA( DRILL DDRL P Directionally drill 12-1/4" F/1458'MD T/2507'MD. Drilling parameters:50 rpm,WOB 20k lbs, 510 gpm,torque off/on 5k/4k ft-lbs, and pressure off/on 1700/1500 psi. P/U 104k lbs, S/O 95k lbs, ROT 95k lbs. ADT 7.58,ART 5.06,AST 2.52,total bit hours-18.37 and total jar hours- 44.76 Offloaded second bulk load of Arctic Set 3 cement at 01:30 hours. 12:00 14:00 2.00 2,507 2,673 SURFA( DRILL DDf2L P Directionally drill 12-1/4"F/2507'MD to TD of 2673'MD Drilling parameters:60 rpm,WOB 20k lbs, 510 gpm,torque off/on 5k/3k ft-lbs, and pressure off/on 1700/1500 psi. P/U 110k lbs, S/0 97k lbs, ROT 60k lbs. ADT 1.9,ART 1.9,AST 0,total bit hours-20.27 and total jar hours- _ 46.66 14:00 15:00 1.00 2,673 2,673 SURFA( DRILL CIRC P Circulate bottoms up. L/D single of drill pipe, rack back 1 stand and circulate second bottoms up. Pump at 575 gpm with 2100 psi and 60 RPM. 15:00 19:15 4.25 2,673 907 SURFA( DRILL REAM P BROOH to HWDP at 906.6'MD. Circulate bottoms up while reaming last stand. Pump at 600 gpm with 1850 psi and 60 RPM. 19:15 20:15 1.00 907 2,673 SURFA( DRILL TRIP P TIH on elevators to 2667'MD. P/U single of drill pipe and wash 6'to TD 2673'MD. Encounter tight spot at 931'MD. Reciprocated through spot once, no further issues. Calculated displacement: 11.25 bbls, actual displacement 11.22 bbls. 20:15 21:15 1.00 2,673 2,673 SURFA( DRILL CIRC P Circulate bottoms up at 550 gpm with 1700 psi and 60 RPM. Attempt to bring on 11.0 ppg spike fluid from vac truck, no success. Truck could not initially provide enough pressure to offload the viscous fluid.The rig hopper pump was used to assist the offloading of the vac truck. 21:15 23:00 1.75 2,673 2,482 SURFA( DRILL REAM P Bring on 11.0 ppg spike fluid and cut sack material to weight up system to 10.0 ppg for 0.4 ppg trip margin. Backream 3 ft/min and rack back stands while displacing hole at 600 gpm with 1900 psi. Pick up casing running and cementing equipment to rig floor. (slips,tongs, elevators, cement head). Page 3 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 2,482 2,300 SURFA( DRILL CIRC P Continue conditioning and circulating mud from 9.6 ppg to 10 ppg at 600 gpm 1900 psi. At 21:15 hours, mud weight in 10.0 ppg and mud weight out 9.8 ppg. At 23:59 hours, mud weight in and out 10.00 ppg. 02/10/2011 Finish conditioning and circulating mud from 9.6 ppg to 10.0 ppg. POOH on elevators to HWDP at 906'MD (19 stands DP). L/D 6 joints of 5"HWDP and rack back remainder of HWDP(6 stands). Reciprocated through several tight spots between 800'-600'MD. UD MWD tools and bit. Rig up casing running equipment. M/U 9-5/8"40#L-80 BTC-M shoe track and circulate 60 bbls through Frank's fill-up tool. Continue running casing to shoe setting depth of 2662.88'MD. Broke circulation on joints#29-30 and#62- 64 while RIH. Circulated 194 bbls(surface to surface)on joint#35 at 1410'MD. Land hanger and R/U cementing equipment. Establish circulation down 9-5/8"casing and stage up rate to 7 bpm. Condition and circulate mud to reduce PV/YP in preparation for cementing. PJSM on cementing. Pump 90 bbls of 10.0 ppg mud with nut plug marker followed by 35 bbls of 8.34 ppg Biozan preflush with nut plug marker. Switch over to Dowell and pump 5 bbls water. Pressure test lines to 3500 psi. Drop bottom plug and pump 54.2 bbls Mud Push II spacer. Pump 247.3 bbls AS lite lead cement followed by 56.3 bbls Alpine tail cement. Drop top plug and kick out with 20 bbls water using Dowell unit. Displace cement with rig mud pump#1 and 10.0 ppg mud. Bump plug at 1750 strokes(175.8 bbls)and pressure up to 1075 psi. Hold pressure for 5 minutes. CIP at 23:59 hrs on 2/10/2011. Landed hanger on landing ring. Circulated 56.4 bbls of good 10.7 ppg cement to surface. 00:00 00:30 0.50 2,300 2,673 SURFA( DRILL TRIP P RIH 4 stands of drill pipe racked back during conditioning and circulating of mud. No fill encountered. 00:30 01:00 0.50 2,673 2,673 SURFA( DRILL OWFF P Monitor well on trip tank for flow. 01:00 02:30 1.50 2,673 906 SURFA( DRILL TRIP P POOH on elevators from 2673'MD to HWDP at 906'MD(19 stands DP). No hole problems encountered. 02:30 03:30 1.00 906 170 SURFA( DRILL PULD P Check well for flow(10 minutes)then UD 6 joints of 5"HWDP. Rack back remainder of HWDP(6 stands). Recorded overpull at 790',730',640', and 610'MD. Reciprocated through each spot several times until no drag was observed. 03:30 04:45 1.25 170 0 SURFA( DRILL PULD P UD jars and NMFDC. Break bit and drain motor. Small piece of wood found lodged in bit. Bit grade: 1-2-WT-2-E-2-NO-TD 04:45 06:00 1.25 0 0 SURFA( DRILL PULD P Download MWD. Break out and UD MWD tools. 06:00 06:30 0.50 0 0 SURFA( DRILL PULD P Lay down tools from the rig floor. 06:30 07:00 0.50 0 0 SURFA( DRILL OTHR P Clean rig floor. 07:00 07:15 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on rigging up to run casing. 07:15 08:30 1.25 0 0 SURFA( CASING RURD P Rig up casing running tools for 9-5/8" casing(long bales,elevators, slips, tongs). 08:30 08:45 0.25 0 0 SURFA( CASING SFTY P Pre job safety meeting on running 9-5/8"40 ppf L-80 BTC-m casing. Page 4 of 41 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 08:45 09:45 1.00 0 105 SURFA( CASING RNCS P M/U 9-5/8"casing shoe track as per detail: Rays Oil tool float shoe joint, thread lock joint, HES Sure Seal II float collar joint.All baker locked. 09:45 10:00 0.25 105 115 SURFA(CASING CIRC P Circulate 60 bbls through float equipment using Franks fill-up tool with 9-5/8"shoe above conductor shoe at 108'. Circulate 3 bpm,4 bpm,5 bpm,and 6 bpm. 10:00 12:00 2.00 115 1,085 SURFA( CASING RNCS P Continue running casing to noon depth of 1085'MD(27 joints). Baker lock pin of 4th joint. Make up torque 10,000 ft lbs. Installed centralizers as plan: 10'above shoe on stop ring, collar of joint#1, 10'below box of joint#2 on stop ring. Every collar to joint#13,then every odd joint to joint#63. Use Run-N-Seal dope on threads. 12:00 12:30 0.50 1,085 1,205 SURFA(CASING RNCS P Circulate joint#29 and#30 in hole with Frank's fill-up tool due to THICK MUD and short displacement volume. Pump 20 bbls each at 2 bpm while running each joint. 12:30 13:00 0.50 1,205 1,370 SURFA( CASING RNCS P Continue to run 9-5/8"40 ppf L-80 BTC-m casing F/1205' T/1370' (joint 34 in the hole). 13:00 13:45 0.75 1,370 1,410 SURFA( CASING CIRC P Make up joint#35,stab Frank's fill-up tool.Circulate 194 bbls (surface-surface), reciprocate 20'F/ 1410'T/1390',staging up F/2 bpm T/3.5 bpm.After 70 bbls pumped, ✓ increase pump rate to 4 bpm, after 90 bbls increase to 5 bpm,after 120 bbls increase pump rate to 6 bpm w/ 400 psi. 13:45 15:30 1.75 1,410 2,475 SURFA( CASING RNCS P Continue to run 9-5/8"40 ppf L-80 BTC-m casing F/1410'T/2475'(jt# 61 in the hole). 15:30 16:15 0.75 2,475 2,590 SURFA( CASING RNCS P While running joint#62,#63 and #64,stab frank's tool and pump 4 bpm while running each joint f/2475' to 2590'. Pumped 97 bbls total. Circulated joints in the hole due to THICK MUD and short displacment volume. 16:15 16:30 0.25 2,590 2,630 SURFA( CASING RNCS P Run joint#65 F/2590'T/2630'. 16:30 16:45 0.25 2,630 2,630 SURFA( CASING RURD P Rig down Frank's fill-up tool. Blow down the top drive. 16:45 17:00 0.25 2,630 2,663 SURFA( CASING RNCS P Make up FMC hanger and landing joint. Remove casing slips. RIH f/ 2630'to land shoe at 2662.88'. PU wt 132k, SO wt 97k. 17:00 17:30 0.50 2,663 2,663 SURFA( CEMEN-RURD P Rig up Dowell/Schlumberger cement head and lines. Page 5 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 21:00 3.50 2,663 2,663 SURFA( CEMEN"CIRC P Establish circulation at 3 bpm with 300 psi. Stage pumps up to 7 bpm with 400 psi. Pumped a total of 1015 bbls. Circulate and condition mud to reduce PV/YP from 40/67 to 34/29. Reduce funnel viscosity from 300 sec/qt to 80 sec/qt. Reciprocate F/ 2662'to 2642'during circulation. 21:00 21:15 0.25 2,663 2,663 SURFA( CEMEN"SFTY P PJSM for cementing 9-5/8"casing with rig crew, cementers, mud engineers, and truck drivers. 21:15 22:00 0.75 2,663 2,663 SURFA( CEMEN"CIRC P Pump 90 bbls of 10.0 ppg mud with nut plug marker(5 ppb)at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker(5 ppb)at 5 bpm with 200 psi. Reciprocated 15'to 20'. P/U 122k lbs and S/O 112k lbs. 22:00 23:15 1.25 2,663 2,663 SURFA( CEMEN"PUCM P Dowell pump 5 bbls water and pressure test lines to 3500 psi,good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer(10.5 ppg), pump at 6 i bpm w/230 psi. Mix and pump 247.3 C./A' bbls(308 sx)AS lite lead cement (10.7 ppg,4.51 cuft/sx,20.7 gal St`'ri water/sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls(272 sx) Alpine tail cement(15.8 ppg, 1.16 cuft/sx, 5.105 gal water/sx), pump at 5.8 bpm with 200 psi.Shut down and drop top plug. 23:15 00:00 0.75 2,663 2,663 SURFA(CEMEN"DISP P Dowell kick out top plug w/20 bbls water,pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi.After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi,slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls(calculated displacement of 1755 strokes with 0.1005 bbls/stroke)and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k lbs to 85k lbs. Landed hanger on landing ring at 2345 hrs(landed at 800 strokes into displacement which was 40 bbls before cement returns).Circulated 56.4 bbls of good 10.7 ppg cement to surface. Page 6 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/11/2011 24 hr Summary Bled off pressure to check floats on the 9-5/8"40 ppf L-80 BTC-m casing, OK. R/D and UD FMC landing joint,casing, and cementing equipment. N/D riser and FMC starter head. N/U FMC wellhead and test metal-metal seals,OK. N/U 13-5/8"BOPE. Modify drilling riser to fit rig elevation and N/U same. Test BOPE to 250 psi low/3500 psi high except for annular to 2500 psi high. Bob Noble,AOGCC Inspector witnessed testing. R/D BOPE testing equipment and R/U DP handling equipment. P/U and rackback 18 joints of 5"DP. Break operations for all hands to attend Theoretical Maximum Performance(TMP)discussion facilitated by RLG. 00:00 00:15 0.25 2,663 2,663 SURFA( CEMEN"OTHR P Bled off pressue to check floats on the 9-5/8"40 ppf L-80 BTC-m casing. Floats holding. 00:15 00:30 0.25 2,663 2,663 SURFA( CEMEN-SFTY P PJSM on R/D cementing equipment and landing joint. 00:30 02:00 1.50 2,663 0 SURFA( CEMEN"RURD P R/D Dowell cement head, back out/lay down FMC landing joint. R/D casing tools. Flush riser and lines of cement. 02:00 05:00 3.00 0 0 SURFA(WHDBO NUND P N/D riser and FMC adapter/starter head. Prepare hanger for wellhead installation. 05:00 07:45 2.75 0 0 SURFA(WHDBO NUND P Bring FMC wellhead equipment into cellar. N/U same. 07:45 08:00 0.25 0 0 SURFA(WHDBO PRTS P Test metal-metal seals to 1000 f/10 minutes.Witness of test by rig supervisor. 08:00 09:30 1.50 0 0 SURFA(WHDBO NUND P N/U 13-5/8"BOPE. 09:30 10:00 0.50 0 0 SURFA( RIGMNT SVRG P Service rig. 10:00 12:00 2.00 0 0 SURFA(WHDBO OTHR P Modify drilling riser to fit rig elevation. Add some length. Clean pits. Double valve annulus valve. 12:00 13:00 1.00 0 0 SURFA(WHDBO RURD P N/U riser and flow line. Rig up to test BOPE. 13:00 13:30 0.50 0 0 SURFA(WHDBO OTHR P Fill hole. Flood choke manifold and BOP stack. Check for leaks,OK. 13:30 13:45 0.25 0 0 SURFA(WHDBO SFTY P PJSM on testing BOPE. Page 7 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 20:15 6.50 0 0 SURFA(WHDBO BOPE P Test BOPE.Witness of test by AOGCC inspector Bob Noble. All tests charted for 5 minutes each. Tested annular to 250 psi and 2500 psi.Tested all valves in choke manifold,choke line, kill line,4" demco valve on mud line,floor safety valve, IBOP,top drive automatic and manual IBOP valves, upper pipe rams(3-1/2"x 6"variable bore), blind rams, lower pipe rams(2-7/8"x 5" variable bore)to 250 psi and 3500 psi. Pipe rams and annular tested e0e with 5"test joint. Performed accumulator test: initial system pressure was 3000 psi, pressure o-� after closure was 1700 psi. Build up 200 psi in 40 seconds and full pressure in 3 minutes 34 seconds. Nitrogen bottles average 2000 psi. Tested PVT and gas alarms. Choke manifold valves#8,9, and 10 required replacing stem packing. Lower VBR's required retesting. 20:15 20:30 0.25 0 0 SURFA(WHDBO RURD P R/D BOPE test equipment. Install wear ring. Blow down kill line,choke line,and choke manifold. 20:30 20:45 0.25 0 0 SURFA( DRILL RURD P R/U to P/U DP via mouse hole. 20:45 21:00 0.25 0 0 SURFA( DRILL SFTY P PJSM on P/U DP. 21:00 21:30 0.50 0 0 SURFA( DRILL PULD P P/U and M/U 18 joints of 5"DP. Rack back same. 21:30 00:00 2.50 0 0 SURFA( DRILL OTHR P Break for all hands to attend Theoretical Maximum Performance (TMP)facilitated by RLG. Note: Excellent participation from both crews. Discussed potential methods to increase efficiency without compromising safety during flat time operations. Developed over 50 action items to investigate for optimizing operations. Feedback provided by crews showed enthusiasm and support for the TMP purpose. 02/12/2011 Held TMP discussion with both day and night crews. P/U 48 stands 5"DP and rack back. P/U and M/U 8-3/4"intermediate drilling BHA. Shallow pulse test MWD equipment,OK. RIH to 2394'MD, circulate and condition mud for casing test. Test 9-5/8"surface casing to 3700 psi, OK. Slip and cut 70'drill line. Continue RIH and tag float plugs above float collar at 2585.1'MD. Drill shoe track, 10'rat hole,and 20'of new formation to a depth of 2693'MD. Condition and circulate mud for LOT/FIT. Perform LOT/FIT. Formation leaked off at 16.9 ppg EMW with 9.6 ppg mud and 930 psi surface pressure. Displace spud mud with 9.6 ppg LSND. Continue drilling from 2693'MD to 2830'MD. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 SURFA( DRILL OTHR P Break for all hands to attend Theoretical Maximum Performance (TMP)facilitated by RLG. Note: Excellent participation from both crews. Discussed potential methods to increase efficiency without compromising safety during flat time operations. Developed over 50 action items to investigate for optimizing operations. Feedback provided by crews showed enthusiasm and support for the TMP purpose. 02:00 02:15 0.25 0 0 SURFA( DRILL SFTY P PJSM on P/U, M/U and standing back 5"drill pipe. 02:15 06:30 4.25 0 0 SURFA( DRILL PULD P P/U and M/U 144 joints(48 stands) of 5"DP via mouse hole. Rack back _ same in derrick. 06:30 07:00 0.50 0 0 SURFA( DRILL PULD P Clear rig floor,bring BHA components to the floor. 07:00 07:15 0.25 0 0 SURFA( DRILL SFTY P PJSM on P/U and M/U 8-3/4" intermediate drilling BHA. 07:15 08:30 1.25 0 83 SURFA( DRILL PULD P M/U BHA#3 as follows:8-3/4" Hughes HCM605Z bit,7"Sperrydrill 7/8-6 stage motor, NM Integral blade 6/A- stabilizer, NM float sub, NM 6-3/4" DM Collar, NM 6-3/4" EWR/DGR/PWD Collar, NM 6-3/4" Pulsar. 08:30 09:15 0.75 83 83 SURFA( DRILL PULD P Upload Sperry Sun MWD. 09:15 11:00 1.75 114 393 SURFA( DRILL PULD P Continue to P/U and M/U BHA#3: (3) 6-1/2"flex collars, run one stand of 5"HWDP,Weatherford jars(ser# 1622-0445), run additional stand of HWDP. 11:00 11:15 0.25 393 393 SURFA( DRILL DHEQ P Shallow pulse test MWD, pump at 450 gpm with 1020 psi. Blow down top drive. 11:15 11:30 0.25 393 730 SURFA( DRILL TRIP P Run 5 stands of 5"HWDP, lay down a single of 5"HWDP(30.70'). 11:30 12:30 1.00 730 2,394 SURFA( DRILL PULD P P/U and M/U 54 joints of 5"drill pipe, single in on top of BHA to 2394' 12:30 13:00 0.50 2,394 2,394 SURFA( DRILL CIRC P Circulate and condition mud for casing test. P/U 102k,S/O 84k, Rot wt 92k. Pump at 5 bpm with 475 psi. 13:00 13:30 0.50 2,394 2,394 SURFA( DRILL RURD P Blow down the top drive. R/U to test casing. 13:30 14:15 0.75 2,394 2,394 SURFA( DRILL PRTS P Test 9-5/8"40 ppf L-80 BTC-m casing to 3700 psi. Chart test f/30 minutes. Lost 10 psi-good test. 14:15 14:30 0.25 2,394 2,394 SURFA( DRILL PRTS P R/D testing equipment. 14:30 14:45 0.25 2,394 2,394 SURFA( DRILL SFTY P PJSM on slipping and cutting drilling line. 14:45 15:30 0.75 2,394 2,394 SURFA( RIGMN7 SLPC P Slip and cut 70'of 1-1/4". Page 9 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:30 15:45 0.25 2,394 2,585 SURFA( DRILL TRIP P Continue RIH and tag float plugs above float collar at 2585.18'MD. 15:45 19:00 3.25 2,585 2,673 SURFA( CEMEN-DRLG P Drill cement float plugs.float collar, cement to float shoe 2662.88'. Clean out rat hole from 2662'to 2673'MD (2464'ND). Pumping 500 gpm w/1090 psi. Rotate 60 rpm w/5k ft-lbs. 2 WOB. P/U 110k, S/O 85k, ROT 96k. 19:00 19:30 0.50 2,673 2,693 SURFA( DRILL DDRL P Drill 8-3/4"F/2673'MD T/2693'MD. Drilling parameters:60 rpm,WOB 5k lbs, 500 gpm,torque off/on 5k/4k ft-lbs,and SPP 1175 psi. P/U 110k lbs, S/O 85k lbs, ROT 96k lbs. ECD 10.1 ppg.ADT 0.19,ART 0.19,AST 0,total bit hours-0.19 and total jar hours-0.19 19:30 20:00 0.50 2,693 2,693 SURFA( DRILL CIRC P Condition and circulate mud for LOT/FIT. Circulate at 511 GPM with 1400 psi until MW in/out 9.6 ppg. 20:00 20:30 0.50 2,693 2,652 SURFA( DRILL RURD P R/U for FIT/LOT. Rack back stand and LJD single. Blow down top drive. Flood cement and kill lines. 20:30 21:00 0.50 2,652 2,652 SURFA( DRILL LOT P Perform LOT/FIT. Formation leaked off at 16.9 ppg EMW with 9.6 ppg LD� mud and 930 psi surface pressure. 9-5/8"shoe at 2662.8'(2457.0'ND). 21:00 21:15 0.25 2,652 2,693 INTRM1 DRILL RURD P R/D test equipment. Blow down lines. P/U single and stand of DP. 21:15 22:15 1.00 2,693 2,693 INTRM1 DRILL CIRC P PJSM. Displace hole and casing to 9.6 ppg LSND mud at 500 gpm with 1250 psi. 22:15 00:00 1.75 2,693 2,830 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/2693'MD T/2830'MD. Drilling parameters:60 rpm,WOB 5-10k lbs,600 gpm, torque off/on 3.5k/5k ft-lbs,and SPP 1200 psi. P/U 104k lbs,S/O 90k lbs, ROT 97k lbs. ECD 10.3 ppg. ADT 0.87,ART 0.78,AST 0.9,total bit hours-1.06 and total jar hours- 1.06 02/13/2011 Directionally drill 8-3/4"intermediate hole section from 2830'MD to 4000'MD to crew change at 12:00pm. At 3320'MD, circulate two bottoms up and pump a 35 bbl sweep due to ECD's trending higher than expected. Continue drilling to midnight depth of 5140'MD. At 4867'MD circulate lubricants into mud system to mitigate erratic torque, no success. Add additional tote of lubricants at 5025'MD to raise lubricants in system up to 1.25%. Erratic torque still observed. Page 10 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:45 3.75 2,830 3,320 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/2830'MD T/3320'MD. Drilling parameters:80 rpm,WOB 3-7k lbs,610 gpm,torque off/on 4k/5k ft-lbs,and SPP off/on 1440/1520 psi. P/U 113k lbs,S/O 97k lbs, ROT 104k lbs. ECD 10.6 PPg• Pump 35 bbl sweep consisting of 3 sacks flowzan at 2980'MD and 3227' MD. Observed 5-10%increase in cuttings volume at shakers. 03:45 04:30 0.75 3,320 3,320 INTRM1 DRILL CIRC P Circulate two bottoms up and a 35 bbl sweep(3 sacks flowzan)due to ECD's trending higher than expected. Actual drilling ECD's 10.8 ppg vs. calculated of 10.4 ppg. Observed slight increase in cuttings volume with sweep. ECD's reduced to 10.3 PPg. 04:30 12:00 7.50 3,320 4,000 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/3320'MD T/4000'MD. Drilling parameters:80 rpm,WOB 6-9k lbs,630 gpm,torque off/on 5k/6k ft-lbs,and SPP off/on 1780/2010 psi. P/U 127k lbs,S/O 103k lbs, ROT 115k lbs. ECD 10.8 ppg.ADT 7.91,ART 7.10,AST 0.81, total bit hours-8.97 and total jar hours-8.97 Pump 35 bbl sweep consisting of 3 sacks flowzan and 7 sacks nutplug at 3533'MD and 3725'MD. Observed 5-10%increase in cuttings volume at shakers. Page 11 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 4,000 5,140 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/4000'MD T/5140'MD. Drilling parameters:80 rpm,WOB 6-9k lbs,630 gpm,torque off/on 5k/6k ft-lbs,and SPP off/on 1780/2010 psi. P/U 127k lbs,S/O 103k lbs, ROT 115k lbs. ECD 10.8 ppg.ADT 6.87,ART 6.02,AST 0.85, total bit hours-15.84 and total jar hours-15.84 Pump 35 bbl sweep consisting of 3 sacks flowzan and 7 sacks nutplug at 4000'MD and 4890'MD. At 20:00 hours,4807'MD perform 250 bbl mud dilution reducing MBT's from 17.5 to 13. At 20:45 hours,4867'MD add 1 tote of Lotorq to reduce erratic torque and slip/stick, unsuccessful. Add additional tote at 22:30 hours, 5025' MD to raise lubricants in system up to 1.25%. Erratic torque still observed. 02/14/2011 Directionally drill 8-3/4"intermediate hole section F/5140'MD T/6527'MD. Pumped 35 bbl sweeps (consisting of flowzan and nutplug)at 5311'MD,5958'MD, and 6133'MD. Performed 275 bbl mud dilution at 5359'MD and 6178'MD. Raised lubricants in system from 1%to 1.5%at 5500'MD then again to 2.0%at 6482'MD. Erratic torque and slip/stick still present but reduced. Page 12 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 12:00 12.00 5,140 5,913 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/5140'MD T/5913'MD. Drilling parameters:95 rpm,WOB 5-8k lbs,650 gpm,torque off/on 4k/5-10k ft-lbs,and SPP off/on 2050/2150 psi. P/U 148k lbs,S/O 133k lbs, ROT 140k lbs. ECD 10.7 ppg.ADT 6.75,ART 3.88,AST 2.87, total bit hours-22.59 and total jar hours-22.59 Pump 35 bbl sweep consisting of 3 sacks flowzan and 7 sacks nutplug at 5311'MD. At 5359'MD perform 275 bbl mud dilution reducing MBT's from 17.5 to 13. At 5360'MD varied drilling parameters to mitigate erratic torque. Tried different combinations of WOB and RPM, no success. At 5500'MD completed the addition of 4 drums of lubricant 776 for a system total of 1.5%. Erratic torque and slip/stick still present. 12:00 00:00 12.00 5,913 6,527 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/5913'MD T/6527'MD. Drilling parameters: 95 rpm,WOB 5-10k lbs,650 gpm, torque off/on 7k/11.5k ft-lbs, and SPP off/on 2100/2100 psi. P/U 159k lbs, S/O 137k lbs, ROT 152k lbs. ECD 10.7 ppg.ADT 8.82,ART 4.25, AST 4.51,total bit hours-31.41 and total jar hours-33.41 Pump 35 bbl sweep consisting of 2 ppb flowzan and 10 ppb nutplug at 5958'MD and 6133'MD. At 6178'MD perform 275 bbl mud dilution reducing MBT's from 17.5 to 14. At 6482'MD lubricants total 2.0%of system. 02/15/2011 Directionally drill 8-3/4"intermediate hole section F/6527'MD T/7264'MD. Pumped 35 bbl sweeps (consisting of flowzan and nutplug)at 6541',6740',6920',7100'MD. Performed 275 bbl mud dilution at 7026' MD. Raised lubricants in system from 2.0% to 3%at 7045'MD. Page 13 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 6,527 6,979 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/6527'MD T/6979'MD(5775'TVD). Drilling parameters:95 rpm,WOB 5-10k lbs, 650-642 gpm,torque off/on 9k/9k ft-lbs,and SPP off/on 1900/2050 psi. P/U 174k lbs, 5/0 142k lbs, ROT 159k lbs. ECD 10.7 ppg.ADT 6.49, ART 2.04, AST 4.45,total bit hours- 37.9 and total jar hours-39.9 Pump 35 bbl sweep consisting of 2 ppb flowzan and 7 ppb nutplug at 6540' ,6740', and 6920'. At 6979'MD lubricants total 2.0%of system. 12:00 00:00 12.00 6,979 7,264 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/6979'MD T/7264'MD(6028'TVD). Drilling parameters: 95 rpm,WOB 5-10k lbs, 640-6432 gpm,torque off/on 9k/10k ft-lbs,and SPP off/on 1860/2050 psi. P/U 180k lbs,S/O 148k lbs, ROT 162k lbs. ECD 10.39 ppg.ADT 6.34, ART.73, AST 5.61,total bit hours- 44.24 and total jar hours-44.24 Pump 35 bbl sweep consisting of 2 ppb flowzan and 7 ppb nutplug at 7100'. At 6979'MD perform 275 bbl mud dilution reducing MBT's from 20 to 16. 02/16/2011 Directionally drill 8-3/4"intermediate hole section F/7264'MD T/7673'MD(6371'TVD). Survey and Slow pump rates. Pumped 35 bbl sweep(consisting of flowzan and 7 ppb nutplug)at 7673'MD with 10%increase in cuttings,while rotating and reciprocating. Back ream out of the hole,traveling 20 to 30 ft/min f/7673'to 3323', pumping 650 gpm w/initial 1900 psi--final 1500 psi. Rotating 80 rpm w/initial 6k ft lbs of torque--final 4k. Rot up wt 140k @ 3323'. No problems. ECD's 10.33 to 10.85 ppg. A 275 bbl whole mud dilution while backreaming @ 4910'.A High vis nut plug sweep while circulating @ 7673'. 00:00 12:00 12.00 7,264 7,580 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/7264'MD T/7580'MD(6028'TVD). Drilling parameters: 95 rpm,WOB 5-10k lbs, 640-6432 gpm,torque off/on 7k/7k ft-lbs, and SPP off/on 1860/2100 psi. P/U 180-185k lbs,S/0 148-152k lbs, ROT 166-170k lbs. ECD 10.37 ppg. ADT 6.86, ART.92, AST 5.94,total bit hours-51.1 and total jar hours- 51.1 Page 14 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:30 3.50 7,580 7,673 INTRM1 DRILL DDRL P Directionally drill 8-3/4"F/7580'MD T/7673'MD(6371'TVD). Drilling parameters:95 rpm,WOB 5-10k lbs, 640-632 gpm,torque off/on 9k/12k ft-lbs, and SPP off/on 1860/2100 psi. P/U 190k lbs, S/O 151k lbs, ROT 171k lbs. ECD 10.33 ppg. ADT 2.61,ART.55, AST 2.06,total bit hours-53.71 and total jar hours- 53.71 15:30 15:45 0.25 7,673 7,673 INTRM1 DRILL CIRC P Survey and Slow pump rates @ 7673'. 15:45 16:30 0.75 7,673 7,673 INTRM1 DRILL CIRC P Pumped 35 bbl sweep(consisting of flowzan and 7 ppb nutplug)at 7673' MD with 10%increase in cuttings, while rotating and reciprocating f/ 7673'to 7578'. 16:30 00:00 7.50 7,673 3,323 INTRM1 DRILL REAM P Back ream out of the hole,traveling 20 to 30 ft/min f/7673'to 3323', pumping 650 gpm w/initial 1900 psi, final 1500 psi. Rotating 80 rpm w/ initial 6k ft lbs of torque,final 4k. Rot up wt 140k @ 3323'. No problems. ECD's 10.33 to 10.85 ppg. A 275 bbl whole mud dilution while backreaming @ 4910'. 02/17/2011 Continue to back ream out of the hole,traveling 10 to 15 ft/min f/3323'to 2800', pumping 650 gpm w/initial 1900 psi--final 1500 psi. Rotating 80 rpm w/initial 4k ft lbs of torque--final 4k. Rot up wt 140k @ 3323'. No problems. ECD's 10.8 to 10.65 ppg. Slowed down f/2800' to 2665'(2'-3'ft/min), ECD's decreased to 10.38 ppg. RIH f/2665'to 2767', pump a 35 bbl nut plug/hi-vis sweep to clean hole while rotating and picking up. ✓ Monitor well f/20 min-static. RIH to 4619', pump surface to surface(diluting w/275 bbls of new mud),while dumping mud f/pit#6 and the hole. Diluted w/275 bbls of new mud.Trip in the hole obtaining PU and SO wt's to 7583',pump a 35 bbl hi-vis/nut plug sweep, bring in spike fluid w/lnhibycol,wash&ream to bottom @ 7673', Circ to weight up f/9.6 ppg to 9.8 ppg. Directional drill 8-3/4"hole f/7673'to 7998'at midnight. 00:00 01:30 1.50 3,323 2,665 INTRM1 DRILL REAM P Back ream out of the hole,traveling 10 to 15 ft/min f/3323'to 2800', pumping 650 gpm w/initial 1900 psi, final 1500 psi. Rotating 80 rpm w/ initial 4k ft lbs of torque,final 4k. Rot up wt 140k @ 3323'. No problems. ECD's 10.8 to 10.65 ppg. Note:Slowed pulling speed at 2800' to 2665'allowing hole to clean up, 2 to 3 ft/min. ECD's dropped to 10.38 ppg as shakers cleaned up. Lots of clay patty's. 01:30 02:15 0.75 2,665 2,767 INTRM1 DRILL CIRC P RIH f/2665'to 2767'. Pump a 35 bbls hi vis sweep w/7 ppb medium nut plug. Pumping 650 gpm w/1450 psi. Rotate 60 rpm w/4k ft lbs of torque. Pull up slow while pumping sweep to clean hole. Circulate until shakers were clean. 02:15 02:45 0.50 2,767 2,767 INTRM1 DRILL OWFF P Monitor well f/20 minutes-static. 02:45 03:00 0.25 2,767 2,767 INTRM1 DRILL OTHR P Blow down the top drive. Page 15 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:15 1.25 2,767 4,619 INTRM1 DRILL TRIP P Trip in the hole 20 stands f/2767'to 4619'.Obtain PU and SO wt's every 5 stands. Fill pipe every 20 stands. _Monitor well on the trip tank. 04:15 04:45 0.50 4,619 4,619 INTRM1 DRILL CIRC P While filling pipe, pump a 275 bbl dilution,dumping mud f/hole and pit #6 which was 20 MBT's. Pumping 650 gpm w/1550 psi, rotate 80 rpm w/4k ft lbs of torque. Reciprocate f/ 4619'to 4526'. Rotating weight wt 112k, 04:45 05:00 0.25 4,619 4,619 INTRM1 DRILL OTHR P Blow down the top drive. 05:00 07:00 2.00 4,619 7,583 INTRM1 DRILL TRIP P Trip in the hole f/4619'to 7583'. Obtain PU and SO wt's every 5 stands. Fill pipe every 20 stands. Monitor well on the trip tank. 07:00 08:00 1.00 7,583 7,583 INTRM1 DRILL CIRC P Pump a 35 bbls high vis sweep w/7 ppb medium nut plug. Pumping 650 gpm w/1900 psi, rotate 80 rpm w/9k ftlbs of torque. Reciprocate from 7583'to 7491'. 08:00 08:30 0.50 7,583 7,673 INTRM1 DRILL REAM P Make a connection,wash to bottom pumping 550 gpm w/1300 psi. PU wt 190k,SO wt 143k,Took weight at 7646'and 7653'. Pick up and ream f/ _7640'to bottom @ 7673'. 08:30 09:30 1.00 7,673 7,673 INTRM1 DRILL CIRC P Circulate and condition mud w/spike fluid w/inhibycol. Weight up f/9.6 ppg to 9.8 ppg. Pumping 650 gpm w/ 1900 psi, rotate 80 rpm w/9k ft lbs of torque, recip f/7673'to 7586'. 09:30 12:00 2.50 7,673 7,745 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/7673'to 7745'(6427'TVD). Drilling parameters:95 rpm,WOB V 10-12k lbs,650-633 gpm,torque on/off 12k/8k ft-lbs, and SPP on/off 2150/2100 psi. P/U 192k lbs, S/O 153k lbs, ROT 171k lbs. ECD 10.36 ppg. ADT 1.43,ART.11, AST 1.32, total bit hours-55.14 and total jar hours-55.14. 12:00 00:00 12.00 7,745 7,998 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/7745'to 7998'(6606'TVD). Drilling parameters: 95 rpm,WOB 8-14k lbs,633-646 gpm,torque on/off 12k/7k ft-lbs, and SPP on/off 2200/2100 psi. P/U 196k lbs, S/O 154k lbs, ROT 174k lbs. ECD 10.39 ppg. ADT 6.31,ART 1.11, AST 5.20,total bit hours-61.45 and total jar hours-61.45. 02/18/2011 Continue to directional drill 8-3/4"hole f/7998'to 8718'(6929'TVD)at midnight. Pumped bit balling sweep @ 8430'and 8615'. Page 16 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 7,998 8,394 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/7998'to 8394'(6821'TVD). Drilling parameters: 95 rpm,WOB 5-13k lbs,630-646 gpm,torque on/off 11 k/8k ft-lbs,and SPP on/off 2350/2100-2175 psi. P/U 204k lbs, S/O 152k lbs, ROT 175k lbs. ECD 10.39-10.51 ppg. ADT 7.55,ART 1.42, AST 6.13,total bit hours-69 and total jar hours-69. 12:00 00:00 12.00 8,394 8,718 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/8394'to 8718'(6929'TVD). Drilling parameters:95 rpm,WOB 5-10k lbs,650 gpm,torque on/off 11.5k/8.5k ft-lbs,and SPP on/off 2350/2225 psi. P/U 200k lbs,S/O 150k lbs, ROT 173k lbs. ECD 10.42 ppg. ADT 7.04,ART 1.48, AST 5.56,total bit hours-76.04 and total jar hours-76.04. Note: Pumped bit balling sweeps @ 8430'and 8615(SAPP, Nut Plug, ScreenKleen) 02/19/2011 Con't to direc ii nal drill 8-3/4"hole f/8718'to 8879'(6953 7'TVD) Circ 2 BU's while recip f/8879'to 8772'. Monitor well f/20 minutes-slight flow. Pump a 35 bbl high vis 11.8 ppg nut plug sweep surf to surf+(7 ppb nut plug,2.5 ppb Flozan), until hole cleans up, no gas cut mud on bottom's up. Pumping 650 gpm w/2250 psi. Rotate 80 rpm w/9.5k ft lbs of torque. Backream out of the hole(/8879'to 8789', monitor well-slight flow, continue to back ream to 7665'. Pumping 650 gpm w/2300 psi initial,2150 psi final. Rotate 80 rpm w/10k to 8k ft lbs of torque. Blow down the top drive, monitor well-static.Trip in the hole f/7665'to 8735',took 40k w/ 35k overpull. Ream through, packed off,stage pumps to 4 bpm w/800 psi, packed off again @ 8750'work to 75k overpull,stand back a stand to 8620'.Circulate bottoms up, ream in the hole to 8726'-tagged a bridge and stalled rotary,work pipe free.Try again to clean hole and get deeper, no success-packed off again. Re establish circulation and rotation-backream to 8693'. Increase pump rate to 650 gpm w/2300 psi and backream up the hole f/8693'to 8600'. Pump a 35 bbl nut plug sweep,then increase mud weight f/9.8 ppg to 10 ppg while backreaming f/8505'to 7765'while weighting up to 10 ppg. 00:00 05:15 5.25 8,718 8,879 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate 1-7 hole f/8718'to 8879'(6953.7 TVD) (TD f/intermediate hole section). y • Drilling parameters:95 rpm,WOB 5-10k lbs,650 gpm,torque on/off 11.5k/8.5k ft-lbs,and SPP on/off 2400/2300 psi. P/U 200k lbs, S/0 140k lbs, ROT 173k lbs. ECD 10.38 ppg. ADT 3.75,ART 1.32, AST 2.43,total bit hours-79.79 and total jar hours-79.79. 05:15 05:30 0.25 8,879 8,879 INTRM1 DRILL CIRC P Obtain final survey. Obtain T&D numbers. 05:30 06:45 1.25 8,879 8,879 INTRM1 DRILL CIRC P Circulate 2 bottom's up while recip f/ 8879'to 8772'. Rotate 80 rpm w/10k ft lbs of torque. Pumping 650 gpm w/ 2250 pi. 06:45 07:15 0.50 8,879 8,879 INTRM1 DRILL OWFF P Monitor well for 20 minutes-slight flow. Page 17 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:45 1.50 8,879 8,879 INTRM1 DRILL CIRC P Pump a 35 bbl high vis 11.8 ppg nut plug sweep surface to surface+(7 ppb nut plug,2.5 ppb Flozan), until hole cleans up. No gas cut mud on bottom's up. Pumping 650 gpm w/ 2200 psi. Rotate 80 rpm w/9.5k ft lbs of torque. ECD's 10.41 ppg. 08:45 09:00 0.25 8,879 8,789 INTRM1 DRILL REAM P Backream out of the hole f/8879'to 8789'. Pump 650 gpm w/2300 psi, rotate 80 rpm w/19k ft lbs of torque. 09:00 09:15 0.25 8,789 8,789 INTRM1 DRILL OWFF P Monitor well-static, 09:15 11:30 2.25 8,789 7,665 INTRM1 DRILL REAM P Continue to back ream out of the hole f/8789'to 7665'. Pumping 650 gpm w/2300 psi initial,2150 psi final. Rotate 80 rpm w/10k to 8k ft lbs of torque. Pu wt 203k, SO wt 146k. 11:30 12:00 0.50 7,665 7,665 INTRM1 DRILL OWFF P Blow down the top drive. Monitor well. 12:00 12:45 0.75 7,665 8,735 INTRM1 DRILL TRIP P Trip in the hole f/7665'to 8735'.Took 40k wt at 8735',w/35k overpull. 12:45 14:30 1.75 8,735 8,750 INTRM1 DRILL REAM T Make a top drive connection to ream area. Packed off,stalled while rotating. Found a spot to circulate, stage up to 168 gpm w/800 psi, establish rotation w/60 rpm,8-10k ft lbs of torque.Attempt to RIH to 8750',stalled and packed off again. Work pipe f/8750'to 8740',jarred free. 14:30 14:45 0.25 8,750 8,620 INTRM1 DRILL TRIP T Set back a stand. Make a top drive connection. Pickup to 8620'. 14:45 17:30 2.75 8,620 8,693 INTRM1 DRILL CIRC P Establish circulation,staged pumps up to 630 gpm w/2300 psi, established rotation w/60 rpm w/9k ft lbs of torque. Circulate bottom's up. PU wt 198k, SO wt 149k. Ream to bottom of stand @ 8693'. 17:30 18:00 0.50 8,693 8,726 INTRM1 DRILL REAM P Ream in the hole f/8693'to 8726', tag up on a bridge, stalled and packed off. Shut down pump and rotary. 18:00 19:30 1.50 8,726 8,693 INTRM1 DRILL CIRC T Work pipe,establish circulation, stage pumps to 504 gpm w/1550 psi, rotate 80 rpm w/10k ft lbs of torque.Attempt to ream to bottom. Unable to get deeper than 8726'-- packed off,stall drill string. Re establish circulation,@ 147 gpm w/ 450 psi, rotate 80 rpm w/10k ft lbs of torque. Back ream to 8693'while establishing circulation to 152 gpm w/410 psi. Page 18 of 41 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 8,693 8,600 INTRM1 DRILL REAM P Back ream f/8693'while increasing pump rate f/352 gpm to 650 gpm w/ 2300 psi. Rotate 80 rpm w/9-10k ft lbs of torque. ECD's 10.41 ppg. Set back stand#86 20:15 22:30 2.25 8,600 8,505 INTRM1 DRILL CIRC P Pump a 35 bbl nut plug hi vis sweep, pumping 650 gpm w/2300 psi, backreaming 2-3'/min w/80 rpm and 9k ft lbs of torque. Ream f/8600'to 8505'. Possible 15-20%increase in cuttings at the shakers when back to surface. Weighting up mud f/9.8 ppg to 10 PP9. 22:30 00:00 1.50 8,505 7,765 INTRM1 DRILL REAM P Backream while weighting up mud system f/9.8 ppg to 10 ppg. Backreamed f/8505'to 7860'with pulling speed of 10'/minute,then slowed to 2-3'/minute f/7860'to 7765'allowing shakers to clean up some. Rot wt w/pump on= 158k, PU wt w/ pump off= 198k, SO wt w/pump off= 150k 02/20/2011 Monitor well f/20 minutes @ 7765'-static, POOH on elevators f/7765'to 6377'-monitor on the trip tank,pump a dry job, POOH on elevators f/6377'to 2580', monitor well-static,attempt to POOH while inside of 9-5/8" casing f/2575'to 2480'-swabbing. Pump out of the hole f/2480'to 1285',monitor well, POOH f/1285'to surface,download MWD, L/D BHA#3,clean floor, MU BHA#4, RIH filling every 10 stands f/655'to 8530', obtaining PU and SO wt's.Circulate bottoms up, Ream in the hole f/8530'to 8625'w/no problems, ream down f/8625'to 8715'w/300 gpm 60 rpm, backream w/120 rpm and 600 gpm-hole is packing off @ 8710', assembly is tore uing up. Ream f/8625'to 8715'several times to clean up, ream in to 8731'@ midnight. 00:00 00:30 0.50 7,765 7,765 INTRM1 DRILL OWFF T Monitor well f/20 minutes @ 7765'- static, POOH on elevators-monitor on the trip tank, 00:30 01:15 0.75 7,765 6,377 INTRM1 DRILL TRIP T POOH f/7765'to 6377'on elevators-monitor on the trip tank, Obtain PU and SO wt's every 5 stands. 01:15 01:45 0.50 6,377 6,377 INTRM1 DRILL CIRC T Pump a dry job,blow down the top drive. 01:45 04:00 2.25 6,377 2,575 INTRM1 DRILL TRIP T Continue to POOH on elevators f/ 6377'to 2575'. One spot @ 5630' w/ 25k drag,wipe-OK. Obtain PU and SO wt's every 5 stands. Monitor well on the trip tank. Calculated fill 41.25 bbls, actual 44.5 bbls. 04:00 04:15 0.25 2,575 2,575 INTRM1 DRILL OWFF T Monitor well @ shoe f/20 minutes- static. 04:15 04:30 0.25 2,575 2,480 INTRM1 DRILL TRIP T Attempt to POOH on elevators,well swabbing pulling inside of 9-5/8" casing(f/2575'to 2480'). Monitor well on the trip tank. 04:30 07:00 2.50 2,480 1,285 INTRM1 DRILL TRIP T Pump out of the hole f/2480'to 1285'. Pumping 126 gpm w/150 psi, pulling 25-27'/min. Monitor well on active pit. Calculated fill 11.25 bbls, actual 9.8 bbls. Page 19 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 1,285 725 INTRM1 DRILL TRIP T POOH f/1285'to 725'. Monitor well on the trip tank. 08:00 08:15 0.25 725 725 INTRM1 DRILL OWFF T Monitor well @ HWDP f/20 minutes- static. Blow down the top drive. 08:15 09:00 0.75 725 175 INTRM1 DRILL TRIP T Stand back 6 stands of 5"HWDP. Monitor well on the trip tank. 09:00 09:15 0.25 175 83 INTRM1 DRILL TRIP T Stand back a stand of 6-1/2"flex collars. Break bit. Monitor well on the trip tank.Calculated fill 22.22 bbls, actual 27.13 bbls. 09:15 10:30 1.25 83 83 INTRM1 DRILL PULD T Download Sperry Sun MWD. Clean floor. 10:30 11:30 1.00 83 0 INTRM1 DRILL PULD T Finish laying down Sperry Sun BHA #3. Monitor well on the trip tank. 11:30 12:00 0.50 0 0 INTRM1 DRILL PULD T Clean and clear rig floor. 12:00 12:45 0.75 0 655 INTRM1 DRILL PULD T PU/MU BHA#4:8-3/4"Bit,8-1/2" NB stab,6-1/2"flex collar,8-1/2" stab, (2)6-1/2"flex collars, (6 stnds) p1 ' 5"HWDP w/jars. B tiA 12:45 18:30 5.75 655 8,530 INTRM1 DRILL TRIP T Trip in the hole w/5"drill pipe f/655' to 8530'(85 stands in the hole),filling every 10 stands.Obtain PU and SO wt's every 10 stands. 18:30 19:30 1.00 8,530 8,530 INTRM1 DRILL CIRC T Circulate bottoms up while recip f/ 8530'to 8430'. Pumping 512 gpm w/ 1200 psi,stage up to 600 gpm w/ 1500 psi. Rotate 120 rpm w/8k ft lbs of torque. Obtain SPR's. 19:30 20:15 0.75 8,530 8,625 INTRM1 DRILL REAM T Ream in the hole w/stand#86 f/ 8530'to 8625'. Backream prior to making a connection. Pumping 600 gpm, rotate 120 rpm w/8k ft lbs of torque. 20:15 22:45 2.50 8,625 8,715 INTRM1 DRILL REAM T Make a top drive connection on stand#87,then ream in the hole f/ 8625'to 8715'. Ream down pumping 300 gpm w/500 psi, rotate 60 rpm w/ 8k ft lbs of torque. Back ream pumping 600 gpm w/1500 psi, rotating 120 rpm w/8-10k ft lbs of torque. Hole packed off @ 8710', started then to back ream slowly to 8625'.Signs of packing off the whole stand. Ream down again f/8625'to 8715'. Hole appears to be OK. _ 22:45 00:00 1.25 8,715 8,731 INTRM1 DRILL REAM T Make a top drive connection on stand#88,then ream in the hole f/ 8715'to 8731'. Pumping 400 gpm w/ 800 pi, rotate 120 rpm w/. 10-11k ft lbs of torque. Packed off and stalled rotary @ 8731'. Establish circulation, trying to ream and clean up the hole f/8731'to 8715'. Page 20 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/21/2011 24 hr Summary Back ream out cleaning the hole up f/8731'to 8715',pump a 35 bbl sweep surf-surf,continue to ream in the hole f/8715'working hole until free to 8879'. Circulate and weight up f/10 ppg to 10.4 ppg,obtain SPR's, monitor well-static,wiper trip f/8810'to 7420'w/tight spots @ 8798', 8556',8549'8503',and 8494'.Monitor well-static,trip in to 8845'(Hole took 35k @ 8758'), circulate bottoms up while reaming to bottom @ 8879', monitor well-static,wiper trip to 8161'w/25k overpull @ 8784'&20k overpull @ 8761'. Monitor well-astatic, Trip in f/8161'to 8761'(35k),Wash and ream 8718'to 8810'concentrating on 8744'to 8794'.Wipe hole twice w/o rotary f/8718'to 8810'.After working hole drag was better.Make a connection, RIH and tag bottom @ 8879', no fill. Circulate bottoms up, POOH f/8879'to 8810', blow down the top drive, prepare to make another 5 stand wiper trip. 00:00 03:00 3.00 8,731 8,715 INTRM1 DRILL REAM T Ream in the hole(stand#88)f/8731' to 8715'. Pumping 500 gpm w/1100 pi, rotate 120 rpm w/10-20k ft lbs of torque. Packed off and stalled rotary. Establish circulation 600 gpm w/ 1500 psi,trying to ream and clean up the hole f/8731'to 8715'. Set back a stand. 03:00 04:45 1.75 8,715 8,715 INTRM1 DRILL CIRC T Pump a 35 bbl sweep, recip f/8715' to 8620'. Pumping 600 gpm w/1500 psi. Rotate 120 rpm w/10k ft lbs of torque. 04:45 09:15 4.50 8,735 8,879 INTRM1 DRILL REAM T Continue to ream in the hole f/8715', hole packed off at 8765',work back up hole to 8715', ream back down, tight hole @ 8870'to 8875', broke free and reamed to 8879'w/no problems. No fill. Returns over the shakers are fine shale. 09:15 13:00 3.75 8,879 8,879 INTRM1 DRILL CIRC P Circulate and weight up f/10.0 ppg to 10.4 ppg. Reciprocate&rotate f/ 8879'to 8800'. Rotate 120 rpm w/ 8-10k ft lbs of torque, Rotating weight 160k. Pumping 600 gpm w/1450 psi. 13:00 13:30 0.50 8,879 8,810 INTRM1 DRILL OWFF P Obtain SPR's. Monitor well-static. Blow down the top drive. 13:30 14:45 1.25 8,810 7,420 INTRM1 DRILL WPRT P Short wiper trip f/8810'to 7420'. Pulled tight @ 8798. 8556'to 8549', 8503'to 8494'.Worked through these spots once w/no problems after. 14:45 15:15 0.50 7,420 7,500 INTRM1 DRILL OWFF P Monitor well @ 7500'-static. 15:15 15:45 0.50 7,500 8,758 INTRM1 DRILL WPRT P Trip back in the hole f/7500'to 8845'. Stage pump rate to 600 gpm w/1500 psi. Establish rotation(120 rpm)w/ 8-10k ft lbs of torque. Hole took 35k weight at 8758'. 15:45 18:45 3.00 8,758 8,879 INTRM1 DRILL CIRC P Circulate bottoms up work down to 8879'(TD).After BU, pump a hi vis nut plug sweep @ 600 gpm w/1550 psi. Rotate 120 rpm w/8-9k ft lbs of torque. Recip 8879'to 8810'. 18:45 19:15 0.50 8,879 8,810 INTRM1 DRILL OWFF P Monitor well @ 8879'-static. Blow down the top drive. Page 21 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 19:45 0.50 8,810 8,161 INTRM1 DRILL WPRT P Wiper trip f/8810'to 8161'. Pulling 20'/min.Overpull @ 8784'(25k)& 8761'(20k). PU wt while tripping 200-205k. SO wt 145K @ 8161'. Proper fill on trip tank. 19:45 20:00 0.25 8,161 8,161 INTRM1 DRILL OWFF P Monitorwell-static. 20:00 20:45 0.75 8,161 8,761 INTRM1 DRILL WPRT P Trip in the hole f/8161'to 8761',took 35k wt. 20:45 22:15 1.50 8,761 8,810 INTRM1 DRILL REAM P Kelly up,wash and ream f/8718'to 8810',concentrating on 8744'to 8794'. Pumping 600 gpm w/1550 psi, 120 rpm w/8k ft lbs of torque. 22:15 22:45 0.50 8,810 8,810 INTRM1 DRILL TRIP P Wipe hole w/o rotary f/8718'to 8810'.Wipe hole twice. PU wt 200k, SO wt 130k.Some drag @ 8752' (30k), 8760'(5k)and 8714'(5k). After working hole better @ 8752'. 22:45 23:30 0.75 8,810 8,879 INTRM1 DRILL CIRC P Make a connection,then RIH to tag bottom @ 8879', no fill.Circulate bottoms up pumping 600 gpm w/ 1550 psi, rotate 120 rpm w/9k ft lbs of torque. 23:30 00:00 0.50 8,879 8,810 INTRM1 DRILL TRIP P POOH f/8879'to 8810'. Set back a stand. Blow down the top drive. Prepare to make another 5 stand wiper trip. PU wt 204k, SO wt 145k. 02/22/2011 Short trip, Circulate bottoms up,Spot Well bore strengthening pill @ 8,879' Follow with 10.4 ppg mud to bit, Monitor well, Pull out spotting WBSP&Cpr @ 2 bpm F/8,879'MD-T/7,790'MD.Trip out of hole on elevators, Monitor at BHA, Rack back HWDP and Jars, Lay down BHA, Flush stack pull and service WB, Clear and clean floor, Cut 78'drill line,Change upper rams to 7"(Sim ops while cutting drill line) Test rams,250 low-3,500 high. Rig down test equip,Set 10-3/Fng. PJSM rig up and run 7"casing T/2,640'MD. Circulate casing volume staging pumps up to 5 bpm w/375 psi. 00:00 00:30 0.50 8,810 8,347 INTRM1 DRILL WPRT P Short trip f/8810'to 8347'. PU wt 205k,So wt 145k. 20k overpull @ 8795'and 10k overpull @ 8760'. 00:30 01:00 0.50 8,347 8,879 INTRM1 DRILL WPRT P Monitor well-static. RIH,tag bottom @ 8879', no problems. 10k drag @ 8830'and 8845'.Wipe f/8755'to 8770' 01:00 02:00 1.00 8,879 8,879 INTRM1 DRILL CIRC P Break circulation @ 8879'w/400 gpm, rotate 120 rpm w/10k ft lbs of torque. Stage pumps up to 600 gpm w/1500 psi.Circulate bottoms up while recip f/8879'to 8810'. 02:00 02:30 0.50 8,879 8,810 INTRM1 DRILL CIRC P Pump 10 bbl wellbore strength pill, follow w/90 bbl casing running pill, chase w/68 bbl 10.4 ppg mud. Pull up f/8879'to 8810'at 25'/min pulling speed, pumping 20 spm w/200 psi. Wellbore strength pill: Sak Black 5 ppb, Safe Carb 20 5 ppb. Casing running pill:Alpine Beads 5ppg, Lube 776 6%. 02:30 02:45 0.25 8,810 8,810 INTRM1 DRILL OWFF P Monitor well-static. Blow down the top drive. Page 22 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:15 0.50 8,810 8,530 INTRM1 DRILL TRIP P Pump and Pull f/8810'to 8530'. Pump 20 spm f/75 strokes per stand. Pull 25'/minute. Record PU and SO wt's.Overpull @ 8792'(10k over) 03:15 03:45 0.50 8,530 8,530 INTRM1 DRILL OWFF P Monitor well-static. RIH one stand. Determine not lined up right on pits. Sucking f/pill pit(wellbore strength fluid), returns to pit#5-gaining fluid. Line up to suck and return f/pit#5. 03:45 05:00 1.25 8,530 7,787 INTRM1 DRILL TRIP P Pump and Pull f/8530'to 7787'(77 stands in the hole). Pump 20 spm f/ 75 strokes per stand. Pull 25'/minute. Record PU and SO wt's. 05:00 05:15 0.25 7,787 7,787 INTRM1 DRILL OWFF P Monitor well-static. 05:15 06:15 1.00 7,787 6,862 INTRM1 DRILL TRIP P Pull out on the trip tank f/7787'to 6862' 06:15 06:45 0.50 6,862 6,862 INTRM1 DRILL CIRC P Pump a dry job. Blow down the top drive. 06:45 12:00 5.25 6,862 659 INTRM1 DRILL TRIP P Continue to POOH f/6,862'MD to 659'MD 12:00 12:45 0.75 659 0 INTRM1 DRILL PULD P Monitor well 20 min, Hold PJSM while monitoring on BHA. Rack back HWDP,Jars. Lay down flex collars, stabilizers and bit. 12:45 14:00 1.25 0 0 INTRM1 DRILL RURD P Flush stack, Pull wear ring,Clear and clean floor / k 14:00 15:30 1.50 0 0 INTRM1 RIGMN7 SLPC P Slip and cut 78'drill line.(Sim ops- change upper rams to 7") 1(., 4,1 15:30 16:15 0.75 0 0 INTRM1 WHDBO BOPE P Test upper 7"rams 250 psi low- 3,500 psi high 5 miinute per test. Rig down test equipment.Set 10-3/8" wear ring. 16:15 18:15 2.00 0 0 INTRM1 CASING RURD P PJSM, Rig up to run 7"casing. 18:15 23:00 4.75 0 2,640 INTRM1 CASING RNCS P Run 7"casing per detail, Baker lok „J N float equipment, Fill and check floats, (Floats good) Run 64 joints G5.). casing to 2640'MD up wt 90k do wt 86k 23:00 00:00 1.00 2,640 2,640 INTRM1 CASING CIRC P Circulate casing volume at 2,640' (Shoe)Stage pumps up slowly to 5 bpm 375 psi final circulating pressure. 02/23/2011 Run 7"casing from 2,640'and to 8,869'.Circulated and conditioned at 4,830'md, 7,016'and and on bottom 8,869'md.Circulating rates staged up from 1 bpm to 5 bpm with final circulating pressure 400 psi. held PJSM, Pressure tested lines, performed 2 stage cement job, 1st stage cement job CIP @ 18:57 2nd stage cement job CIP @ 21:09. Rigged down from cement job. Pulled landing joint,drained stack,set and tested 7" packoff to 5,000 psi. Pressure test witnessed by rig supervisor. Cleared and cleaned floor in preparation for laying down 5"drillpipe. 00:00 03:15 3.25 2,640 4,830 INTRM1 CASING RNCS P Run 7"casing f/2,640'and-V 4,830' md. Obtain up and down weight every 10 joints. Page 23 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:30 1.25 4,830 4,830 INTRM1 CASING CIRC P Circulate and condition mud.Very thick dehydrated mud. Mud weight out 10.7 ppg. Lower mud weight to 10.4 ppg. Initial circulating rate 2 bpm-300 psi,final circulating rate 5 bpm-450 psi.Circulated over surface to surface volume. up wt 135k down wt 105k 04:30 07:45 3.25 4,830 7,016 INTRM1 CASING RNCS P Run 7"casing f/4,830'and-V 7,016' md. Obtain up and down weight every 10 joints. 07:45 09:30 1.75 7,016 7,016 INTRM1 CASING CIRC P Circulate and condition mud, Break circulation at 2.5 bpm-350 psi, stage pumps up to 5 bpm-500 psi. Final circulating pressure at 5 bpm- 450 psi. 09:30 12:15 2.75 7,016 8,869 INTRM1 CASING RNCS P Complete running 7"casing,make up landing joint.Total joints run 214. Casing depth 8,869'md. 12:15 12:45 0.50 8,869 8,869 INTRM1 CEMEN"RURD P Rig down casing tongs, remove slips, rig down Franks fill up tool, Blow down top drive. Rig up cement head. 12:45 17:00 4.25 8,869 8,869 INTRM1 CEMEN"CIRC P Circulate and condition mud for cement job. Initial circulating rate 1 bpm-250 psi final circulating rate 5 bpm-600 psi. Rate staged up 1/2 bpm until final circulating rate reached. Final circulating pressure at 5 bpm-400 psi. Up wt 245k dn wt 145k. ( PJSM for cementing held while circulating.) 17:00 19:15 2.25 8,869 8,869 INTRM1 CEMEN"CMNT P Pump surface volume CW100 pressure test cement line to 3,500 psi,Continue pumping CW100, Drop 54 - top plug 25 bbl's CW100 pumped, Pump 5 bbl's CW100 total CW100 pumped 30 bbl's. batch and pump 27 r bbl's 11.5 ppg Mudpush II spacer, Batch cement and pump 15.8 ppg CM1' lead slurry,volume pumped 53 bbl's. Shut down drop top plug chase with 20 bbl's water,Turn over to rig displace at 5 bpm bump plug at 3,104 strokes total mud pumped 314 bbl's. Casing reciprocated 20' stroke length throughout job up wt 245k dn wt 145k, Casing landed on hanger with CIP @ 18:57.final circulating pressure 400 psi, Pressure up 700 psi over FCP held for 5 minutes, bled pressure off checked floats( Floats Good) Pressure up to 3,400 psi to open stage collar at 5,324'md. 19:15 20:00 0.75 8,869 8,869 INTRM1 CEMEN"CIRC P Circulate and condition mud for 2nd stage cement job. @ 5 bpm-300 psi, Increased rate to 6 bpm-600 psi Page 24 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:15 1.25 5,324 5,324 INTRM1 CEMEN"CMNT P 2nd stage cement iob, Pump 30 bbl's pumped, Pump 28 bbl's 11.5 ppg Mudpush II spacer, Mix and pump 48 bbl's 15.5 ppg tail slurry, Drop top ziwA plug, Flush cement lines with water turn over to rig displace cement with 184 bbl's mud, Displace at 6 bpm- 270 psi, Bump plug with 1,790 strokes, Pressure up to 1,850 psi close stage collar, (Stage collar @ 5,324'md)pressure up to 2,300 psi hold for 5 minutes, bleed pressure confirm stage collar closed.CIP @ 21:09 21:15 00:00 2.75 0 0 INTRM1 CEMEN"RURD P Blow down lines, Rig down cement and casing equipment, lay down landing joint, Pull wear bushing, Install 7"packoff,Test packoff to 5,000 psi for 10 minutes,Test witnessed by Conoco rep. Lay down long bales, Prep floor to lay down 5" drillpipe. 02/24/2011 Changed out top pipe rams, Layed down 285 joints 5"drillpipe with 17 joints HWDp and jars, Injectivty test, Flushed and freeze protected annulus, Picked up 20 stands 4"drillpipe,Tested BOPE 00:00 02:30 2.50 0 0 INTRM1 WHDBO NUND P Change top pipe rams f/7"to 3-1/2" X 6"variables.Sim-ops. Rig up short bales, Elevators,Mousehole, lay down tongs. ✓ 02:30 11:00 8.50 0 0 INTRM1 DRILL PULD P Lay down 285 joints 5"drillpipe, 17 joints HWDP and jars. Sim-ops. Perform injectivity test formation broke down @ 674 psi.Total volume pumped=7 bbl's. Flush annulus with 300 bbl's water at 4 bpm-850 psi, Freeze protect annulus with 65 bbl's diesel at 4 bpm-650 psi.Clear and clean floor, Blow down lines, Rig down Schlumberger. 11:00 12:00 1.00 0 0 INTRM1 WHDBO BOPE P _Pressure test upper variable pipe rams(3-1/2" X 6")250 low psi- 3,500 high psi. 5 minute per test.All tests charted. 12:00 16:45 4.75 0 0 INTRM1 DRILL RURD P Rig down test equipment, Instal 7"ID wear ring,Change out saver sub, remove casing equipment via beaver slide, Load pipe shed with clean out BHA, pick up Geo-Span, Double valve upper annulus, Clear floor of 5" handling equip, Pick up 4"handling equipment. 16:45 19:00 2.25 0 0 INTRM1 DRILL PULD P Pick up 60 joints 4"drillpipe using mousehole. 19:00 20:30 1.50 0 0 INTRM1 WHDBO BOPE P Rig up for BOP test Page 25 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 0 0 INTRM1 WHDBO BOPE P Test BOPE,Test Choke manifold valves#1-14,top variable pipe rams, Upper IBOP and lower IBOP, Manual kill and choke, HCR kill and choke,4" dart valve and TIW valve, kill line demco valve,to 250 low-3,500 high pressure 5 minutes per test,Test annular 250 low psi-2,500 high pressure.All tests charted.Witness of test waived by AOGCC rep's Chuck Sheave/Matt Herrera 02/25/2011 Complete BOPE test(Waived by AOGCC rep Chuck Sheave)Prep for and begin to pick up cleanout assembly,04:00 Phase III weather conditions. Rig waiting on weather(W.O.W.) 00:00 02:00 2.00 0 0 INTRM1 WHDBO PRTS P Complete BOPE test,Test Lower pipe rams 250 low psi-3,500 high psi, 5 min per test all tests charted, Koomey unit system pressure 3,000 AOP psi, after closed 1,800 psi,200 psi attained 35 sec,full pressure --r5 attained 178 sec. 5 bottle nitrogen average=2,220 psi,Test blind rams, CV-3. Rig down from BOPE test, Blow down lines, Instal wear bushing.(Sim-ops load and strap pipe in pipeshed. 02:00 04:00 2.00 0 0 INTRM1 DRILL PULD P Prep for picking up cleanout BHA. Bring short tools to floor via beaver slide. PJSM, Pick up partial cleanout BHA. Bit, Near bit stabilizer,float sub, NM Flex drill collar. (Suspend operations at this point due to Phase III weather conditions.) 04:00 00:00 20.00 0 0 INTRM1 DRILL OTHR T Phase III conditions.All rig operations suspended. Hold safety meeting discuss weather, No travel unless emergency situation. Use buddy system, Notify driller when going to camp and call to confirm arrival at camp.All service personnel advised. Safety audits performed. Table top drill on rig evacuation, H2/S held.All rig entrances exits are being kept clear of snow and ice build up. 02/26/2011 Wait on weather to 12:00 hrs. make up cleanout bha,single in with 4"drillpipe,CBU,test casing to 1,000 psi -10 min. Drill excess cement and stage collar, ream down 3 more stands(No cement stringers)CBU,Test casing 1,000 psi-10 min, pump dry job start out of hole pulled f5,646'and-t/4,517' 00:00 12:00 12.00 0 0 INTRM1 DRILL OTHR T Phase III weather conditions, Rig activities suspended.All entrances and exits kept clear of snow and ice. Check equipment for packed snow from high winds. Page 26 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:30 5.50 0 5,238 INTRM1 DRILL TRIP P Pick up remaining Celanout BHA, Single in hole with 4"drillpipe t/5,175' md,Trip in from derrick t15,280'md. Cement tagged-Rack back stand. Up wt 105k down wt 80k,Calculated displacement 31 bbl's-actual displacement 31 bbl's 17:30 18:15 0.75 5,238 5,238 INTRM1 DRILL CIRC P Circualte bottoms up 200 gpm-550 psi,33%flow out. 18:15 19:00 0.75 5,238 5,238 INTRM1 DRILL PRTS P Rig up and pressure test casing to 1,000 psi for 10 min.Test charted 19:00 21:15 2.25 5,238 5,324 INTRM1 CEMEN"COCF P Trip in to top of cement 5,280'. Drill excess cement and stage collar 245 gpm,600 psi,60 rpm. Stage collar tagged on depth 5,324'. Up wt 105k dn wt 80k rot wt 93k torque 2-3k 21:15 21:45 0.50 5,324 5,646 INTRM1 DRILL REAM P Work through stage collar area twice, continue to wash and ream down to 5,646'No cement stringers encountered. 21:45 22:30 0.75 5,646 5,646 INTRM1 DRILL CIRC P Circulate bottoms up @ 300 gpm with 875 psi, Blow down top drive, 22:30 23:00 0.50 5,646 5,646 INTRM1 DRILL PRTS P Rig up and pressure test casing to 1,000 psi for 10 min.Test charted, Monitor well(Static)Pump dry job, Blow down lines and kill line. Rig down test equipment. 23:00 00:00 1.00 5,646 4,517 INTRM1 DRILL TRIP P Trip out f/5,646'and-1/4,517'md. 02/27/2011 Trip out, Lay down clean out BHA, Make up production BHA,Trip in picking up singles,to 8,662', Circulate bottoms up,test casing.Wash and ream tag cement @ 8,694'drill excess cement to 8,742' 00:00 02:00 2.00 4,517 0 INTRM1 DRILL TRIP P Trip out f/4,517'to surface, Lay down Ceanout assembly. Bit showed no wear. 02:00 07:30 5.50 0 402 INTRM1 DRILL PULD P Pick up Geo-Pilot assembly, Load MWD data, Pulse test 225 gpm 900 psi,Send successful downlink to geo-pilot, load sources,Make up remaining bha. 07:30 16:30 9.00 402 8,662 INTRM1 DRILL TRIP P Trip in hole picking up 4"drillpipe from pipeshed, Displacement calculated-53.2 bbl's actual displacement 54 bbl's. up wt 165k dn wt 95k 16:30 17:15 0.75 8,662 8,662 INTRM1 DRILL CIRC P Circulate bottoms up @ 5 bpm 1,675 psi,30 rpm,torque 6k, rot wt 120k pumps on. Final circulating pressure @ 5 bpm 1,500 psi. Pumps off up wt 160k,dn wt 105k, rot wt 129k,torque 7k. 17:15 19:00 1.75 8,662 8,662 INTRM1 DRILL PRTS P lay down single, blow down top drive, rig up and test 7"casing 30 minutes with 3,500 psi.Test charted. Rig down from test, blow down kill line and cement line, make up single, Make connection on stand#89. Page 27 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 8,662 8,742 INTRM1 DRILL WASH P Wash down and tag cement at 8,694' md.drill hard cement with 50 rpm using 220 gpm 1,420 psi.T/8,742' and 02/28/2011 Drill out cement and casing float equipment, Drill 20'new hole, Displace to 9.5 flo thru mud, Perform LOT to 12.5 ppg EMW, Obtain PWD baseline, Drill ahead f/8,899'and to 9,643'and 00:00 06:00 6.00 8,742 8,787 INTRM1 CEMEN"COCF P Drill Baffle collar tagged on depth at 8,742'md. Float collar tagged on depth at 8,784'md.Very hard cement.flow rate 210 gpm-1,500 psi, rotary-50 rpm,torque 7k, bit wt 2k-10k. 06:00 08:00 2.00 8,787 8,879 INTRM1 CEMEN-DDRL P 8,787'and-Drill cement,7"casing shoe and rathole to 8,879'and flow rate 210 gpm-1,500 psi, rotary-50 rpm,torque 7k, bit wt 2k-10k. 08:00 08:30 0.50 8,879 8,899 INTRM1 DRILL DDRL P Drill 20'new formation f/8,879'and to 8,899'and 6,956'TVD. flow rate 210 gpm- 1,500 psi, rotary-50 rpm, torque 7k,bit wt 5k.ADT.54. Bit and jar hrs.54 08:30 10:30 2.00 8,899 8,899 INTRM1 DRILL CIRC P PJSM, Displace to 9.5 ppg flo-thru mud, 5 spm-216 gpm,2,000 psi, 10.8 ecd. rotary speed 70 rpm, torque 7k 10:30 12:30 2.00 8,899 8,899 INTRM1 DRILL LOT P Rack back stand, Blow down lines, rig up and perform L.O.T.to 12.5 ppq EMW,4 spm to 1,100 psi. Mud weight 9.5 ppg. Bleed off pressure, blow down, rig down from test 12:30 13:30 1.00 8,899 8,899 PROD1 DRILL DDRL P Make up stand,wash to bottom, Obtain PWD baseline 13:30 00:00 10.50 8,899 9,643 PROD1 DRILL DDRL P Drill f/8,899'md-t/9,643'md,6,980' tvd. Flow rate 225 gpm, 1,700 psi, rotary 120 rpm,torq on 7k off 5k,bit wt 5k-10k, up 147k,do 107k, rot 120k, Flow 35% ECD 10.53. ART/ADT 7.24 hrs. Bit&jar hrs. 7.78. SPR's taken @ 9,047 md, 6,969 tvd#1 pump 20 spm-450 psi, 30 spm 700 psi.#2 pump 20 spm 510 psi, 30 spm 770 psi. 03/01/2011 Drill production interval F/9,643'md,Slight flow during connection @ 10,176 md.Weight up flo-thru mud from 9.5 ppg to 9.7 ppg.Well monitored at connections found static. Depth at 24:00 hrs-11,156'and Page 28 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 9,643 10,365 PROD1 DRILL DDRL P Drill F/9,643'MD-T/10,365'MD TVD=6,994'Flow check @ 10,176' MD slight flow,Weight up flo-thru mud from 9.5 ppg to 9.7 ppg while drilling. Bottoms up after connection @ 10,176'and showed flow increase of connection gas to 7%.With 9.7 ppg mud to surface connection @ 10,270'and showed flow increase of only 3%. Degasser running in pits, Further connections showed no flow increase.Well monitored at connections found Static. Drilling parameters flow 225 gpm, 1,700 psi, flow out 35%rpm 120,torque on 7.5k off 5k, ECD with 9.7 ppg= 10.64, bit wt 5k-10k Up 151k,do 105k, rot 130k.ADT/ART=8.55 hrs. Bit and jar hrs=16.33.SPR's @ 10,365'and TVD 6,994'#1 mudpump 20 spm=430 psi 30 spm=690 psi. #2 mudpump 20 spm=460 psi, 30 spm=720 psi.270 bbl mud dilution done as needed. 12:00 00:00 12.00 10,365 11,156 PROD1 DRILL DDRL P Drill F/10,365'MD-T/11,156'MD TVD=6,998'Flow rate 225 gpm, 1,875 psi, 120 rpm,torq 8.5k on, 7k off, Flow out 35%, Mud wt 9.8 ppg, ECD=10.85. up 155k,do 102k, rot 120k,ADT/ART 8.99,Total bit and jar hrs-25.32.SPR's taken at 10,646'and-6,993'tvd with #1 pump=20spm 450 psi, 30 spm 720 psi.#2 pump 20 spm=510 psi, 30 spm=780 psi. 270 bbl mud dilution as needed. Flow check at connections well static. 03/02/2011 Drill F/11,156'and-T/11,964'md.Observed flow at connection. 10 bbl gain, 13:05 Well shut in.Shut in using upper pipe rams with choke closed. SIDPP=110 psi, SICP= 110 psi,Weight up to 10.1 ppg circulating thru choke, Shut down pump let pressure bleed down. Pressure 0 open well and monitor, Flow after 10 min,shut in well,SIDPP=30 psi SICP=30 psi,Weight up to 10.3 ppg.Circulate thru choke with hydril closed @ 2 bpm initial circulating rate Initial circulating pressure 400 psi, 1,200 strokes @ 2 bpm circulating pressure 360 psi, Increase pump rate to 30 spm circulating pressure 710 psi. Pump surface to surface volume 10.3 ppg mud. Shut down and monitor pressure SIDPP 10 psi SICP 0 psi. 10 minute check SIDDP and SICP equalized to 10 psi, Open bleed off and choke. Open hydril monitor for flow.Well Static. 00:00 12:00 12.00 11,156 11,869 PROD1 DRILL DDRL P Drill F/11,156'MD-T/11,869'MD TVD=7,002'Flow rate 225 gpm, 1,925 psi, 120 rpm,Torq on 10k off 6k, Flow out 35%, ECD-11.05. Bit weight 5k-10k,ADT/ART=8.45 hrs. Total bit and jar hrs=33.77. Up 157k, DN, 103k, ROT 127k. SPR's @ 11,210'MD 7,000'TVD, MW 9.8. #1 pump 20 spm 470 psi, 30 spm 720 psi,#2 mudpump 20 spm 500 psi,30 s.m 790 psi. Page 29 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 11,869 11,964 PROD1 DRILL DDRL P Drill F/11,869'MD-T/11,964'MD ND=7,001' Flow rate 222 gpm, 1,925 psi, 120 rpm,Torq on 9.5k off 6.5k, Flow out 35%, ECD-10.96. Bit weight 5k-10k,ADT/ART=1.11 hrs. Total bit and jar hrs=34.88. Up 155k, DN, 100k, ROT 126k. 13:00 13:30 0.50 11,964 11,964 PROD1 WELCTI KLWL T Observed flow after connection @ 11'964'. 10 bbl gain with flow increasing.Well shut in @ 13:05 using upper pipe rams with choke closed. Lined up on gas buster. SIDPP 110 psi SICP 110 psi. Filled pill pit with 35 bbl's mud began weighting up to 10.1 ppg. 13:30 17:30 4.00 11,964 11,964 PROD1 WELCTI KLWL T Pump 30 bbl's 10.1 ppg mud from pill pit at 2 bpm, ICP 580 psi. Noticable crude in returns, Mud weight out 9.7 ppg.Weight up surface system to 10.1 ppg, Pump mud down hole at 20 spm ICP 570 psi, FCP 490 psi. Total strokes pumped 4,200. 10.1 ppg mud at surface. 17:30 19:00 1.50 11,964 11,964 PROD1 WELCTI KLWL T Continue circulating another bottoms up at 3 bpm,720 psi.Strokes pumped 2,400.Total strokes pumped for weight up 6,880. Shut down pump @ 19:05. Let pressure bleed off. Shut in choke SIDPP 20. SICP 10. Pressure equalized in 10 minutes. 19:00 19:30 0.50 11,964 11,964 PROD1 WELCTL KLWL T Opened choke monitored for flow through gas buster. 10 min 0 flow. monitored additional 15 min with no flow. 19:30 20:00 0.50 11,964 11,964 PROD1 WELCTI KLWL T Open standpipe bleed off, Choke full open no pressure open rams.Work string to ensure pipe free. Rack back stand. Make up topdrive pump 10 bbl's through lines to avoid freezing up. Monitor well very slight flow after 10 min. Shut well in using Hydril with choke closed. Record SIDPP 30 psi SICP 30 psi. Page 30 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 11,964 11,964 PROD1 WELCTL KLWL T Circulate thru choke at 2 bpm, weight up pill pit to 10.3 ppg. Pump pill pit volume 30 bbl's down hole at 10 spm while weighting up surface system to 10.3 ppg. Pump 10.3 ppg mud down hole at 20 spm ICP 400 psi,at 1,200 strokes circulating pressure 360 psi. Increase flow rate to 30 spm ICP 740 psi. 3,540 strokes 10.3 ppg mud at surface FCP-840 psi. Shut down pump. monitor for flow thru gas buster with choke open 5 min. No flow.Shut choke.SIDPP 10 psi,SICP 0 psi. After 10 min SIDPP 10 psi,SICP 10 psi, Open Choke,Open standpipe blled off, Open hydril.5 min flow check,Work string to ensure free. Continue flow check. Crew Change. 03/03/2011 Completed weighting up to 10.3 ppg, Monitored well, Circulated bottoms up X 2,Observed flow increase at bottoms up 1st circulation,Shakers blinded off with Bi-carb, sand and crude. Monitored well, Performed exhale test to check for wellbore breathing. Circulated bottoms up, No gas evident no flow increase. Shut down monitored well.Took 5 min readings on returns.Total flow return 2.7 bbl's. Flow stopped well static. Monitored well for 1/2 hr with well remaining static. Continued drilling F/11.964'and-T/13,091'md. 00:00 00:15 0.25 11,964 11,964 PROD1 WELCTL OWFF T Monitor well through open choke. Very slight flow decreasing to no flow. 00:15 02:00 1.75 11,964 11,964 PROD1 WELCTL CIRC T Circulate 2 bottoms up at reduced rate 185 gpm, 1,550 psi, 100 rpm,6k Torque, 11.6 ECD ppg.2,150 strokes pumped flow increase noted. Observed gas bubbling at bell nipple. Shakers blinded off with Bi-Carb, Sand and crude 50 bbl's lost over shakers.2nd circulation pumps staged up to full rate 225 gpm,2,000 psi, 120 rpm,Torque 7.5k, 11.4 ECD, No flow increase or gas shows at bottoms up during 2nd circulation. 02:00 03:00 1.00 11,964 11,964 PROD1 WELCTLOWFF T Blow down top drive and mud lines. Monitor well 30 min,Observed slight flow 1 bbl increase in trip tank after 30 min. 03:00 03:30 0.50 11,964 11,964 PROD1 WELCTL OWFF T Perform exhale test checking wellbore for breathing. SIDDP 30 psi, SICP 0 psi. record pressure every 5 min. SICP increased at 10 psi every 5 min to 30 psi. Pressure held constant at 30 min SIDPP increased to 50 psi. SICP at 30 psi. 03:30 04:30 1.00 11,964 11,964 PROD1 WELCTL CIRC T Circulate bottoms up check for gas. Circulate at 210 gpm,2,000 psi, 120 rpm, ECD 11.46 ppg. Noted minor connection gas at bottoms up. Page 31 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 11,964 11,964 PROD1 WELCTt OWFF T Observed well for flow, Slight flow noted. Recorded flow return rate in 5 min increments. 10 min 2.3 bbl's return at 1 hr total return 2.7 bbl return with flow stopped. Monitored well for an additional 1/2 hr with no flow visible or detected. 06:00 12:00 6.00 11,964 12,300 PROD1 DRILL DDRL P Drill F/11,964'MD-T/12,300'MD ND 7,002. Flow rate 225 gpm, 2,000 psi, 120 rpm,Torq on 11k off 8k, Flow out 37%, ECD-11.58. Bit weight 5k-10k,ADT/ART=3.89 hrs. Total bit and jar hrs=38.77. Up 157k, DN, 95k, ROT 125k.SPR's @ 11,964'MD 7,000'ND#1 pump 20 spm-640 psi 30 spm 800 psi.#2 pump 20 spm 560 psi 30 spm 780 psi. 12:00 00:00 12.00 12,300 13,091 PROD1 DRILL DDRL P Drill F/12,300'MD-T/13,091'MD ND 7,018'. Flow rate 220 gpm, 2,150 psi, 120 rpm,Torq on 12k off r/ 10k, Flow out 38%, ECD-11.69. Bit weight 5k-12k,ADT/ART=8.86 hrs. Total bit and jar hrs=47.63. Up 168k, DN,95k, ROT 125k. SPR's @ 12,433'MD 7,008'ND#1 pump 20 spm-550 psi 30 spm 830 psi.#2 pump,20 spm 550 psi,30 spm, 820 _ psi. 03/04/2011 Continue drilling from 13,091'MD-14,596'MD. Circulate at full drilling rate, racking back 1 stand every 1/2 hr. (220 gpm-2,300 psi -120 rpm-torq 9k.)Circulated 323 bbl's monitored well prior to racking back stand. Slight flow,Continue circulating. 00:00 12:00 12.00 13,091 13,884 PROD1 DRILL DDRL P Drill F/13,091'MD-T/13,884'MD ND 7,025'. Flow rate 220 gpm, 2,300 psi, 120 rpm,Torq on 12k off 9k, Flow out 36%, ECD-11.76. Bit weight 8k-12k,ADT/ART=8.85 hrs. Total bit and jar hrs=56.48. Up 170k, DN, 90k, ROT 120k. SPR's @ 13,185'MD 7,023'ND#1 pump 20 spm-560 psi 30 spm 800 psi.#2 pump,20 spm 590 psi, 30 spm,810 psi. Hole taking fluid at 5 bph rate. Total fluid loss this tour 57.5 bbl's. 12:00 22:00 10.00 13,884 14,596 PROD1 DRILL DDRL P Drill F/13,884'MD-T/14,596'MD ND 7,026'. Flow rate 220 gpm, 2,450 psi, 120 rpm,Torq on 13k off 10k, Flow out 35%, ECD-11.77. Bit weight 10k-12k,ADT/ART=8.2 hrs. Total bit-jar hrs=64.68. Up 180k, DN, 84k, ROT 127k.SPR's @ 14,596'MD 7,028'ND Mud weight 10.3 ppg Time 23:45 #1 pump 20 spm-490 psi 30 spm 880 psi.#2 pump,20 spm 500 psi, 30 spm,880 psi. Tour mud losses total 68 bbl's Loss rate 5.5 bbl's per hr. Page 32 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 14,596 14,596 PROD1 DRILL CIRC P Circulate and condition mud prior to trip to shoe. Circulate 2 X bottoms up racking back stand every 1/2 hr.220 gpm,2,300 psi, 120 rpm,torq 10k, Circulated 323 bbl's monitored for flow prior to racking back stand slight flow visible. 03/05/2011 Monitor well for flow, Backream to shoe,Service rig, slip and cut drill line, pick up 42 joints drillpipe,trip to bottom, Drill F/14,596'MD-T/14,837'MD 00:00 01:30 1.50 14,596 14,409 PROD1 DRILL CIRC P 14,596'Rack back stand, Rotate and reciprocate F/14,502'MD-14,409' MD.220 gpm,2,350 psi, 120 rpm, 10k torque. 01:30 03:00 1.50 14,409 14,409 PROD1 DRILL OWFF P Monitored well for flow. Initial return 3/4 bbl's in 15 min. Continue monitoring with flow decreasing to 1/4 bbl return next 15 min, Continue monitoring with next 15 min check return volume gauged at 1/10th of a bbl. Monitor for an additional 15 minutes with very slight flow visible return calculated at less than 1/10th of a bbl. Continued to monitor with return flow decreasing to minimal amount. Return volume was so slight it was an unmeasurable return. Monitored additional 5 minutes with wellbore static. 03:00 13:00 10.00 14,409 8,860 PROD1 DRILL REAM P Backream Out F/14,409'MD-T/ 8,860'MD Into 7'Casing shoe. 220 gpm,2,300 psi, 120 rpm,torque 11k Up 180k, Dn 90k, Rot 125k. Pulling speed 3 min per stand. Kick drill held 1.5 min response time. Pick up r/ weight at shoe 150k,slack off at shoe 100k. 13:00 13:30 0.50 8,860 8,860 PROD1 DRILL OWFF P Monitor well(Static) 13:30 14:30 1.00 8,860 8,860 PROD1 RIGMN7 SLPC P Slip and Cut 97'(15 wraps)Drill line Service top drive. 14:30 20:00 5.50 8,860 14,595 PROD1 DRILL TRIP P 8,860'-Trip in picking up 42 joints 4", Continue tripping in from derrick to 14,595'.Wash last stand to bottom. Displacement 23 bbl actual, Calculated displacement-32.4 bbl's. 20:00 00:00 4.00 14,595 14,837 PROD1 DRILL DDRL P Drill F/14,596'MD-T/14,837'MD, TVD 7,024'MD. Flow rate 220 gpm, 2,350 psi, 120 rpm,Torq on 13.5k off 10.5k, Flow out 35%, ECD-11.72. Bit weight 10k-12k,ADT/ART=2.65 hrs.Total bit-jar hrs=67.33. Up 178k, DN, 82k, ROT 130k. SPR's @ 14,128'MD 7,022'TVD Mud weight 10.3 ppg Time #1 pump 20 spm- 540 psi 30 spm 860 psi.#2 pump, 20 spm 590 psi, 30 spm, 870 psi. Page 33 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/06/2011 24 hr Summary Drill to TD @ 15,742'MD-7,008'TVD.Circulated hole clean, Backreamed F/15,742'MD-T/14,590'MD, Tripped to bottom on elevators with no difficulties or evidence of hole problems,Circulated 3 X bottoms up 220 gpm,2,300 psi, 90 rpm, 10.5k torque, Monitor well 30 min, 00:00 12:00 12.00 14,837 15,601 PROD1 DRILL DDRL P Drill F/14,837'MD-T/15,601'MD TVD 7,015'. Flow rate 220 gpm, 2,400 psi, 120 rpm,Torq on 13k off 11k, Flow out 35%, ECD-11.75. Bit weight 7k-10k,ADT/ART=9.27 hrs. Total bit-jar hrs=76.60. Up 185k, DN, 74k, ROT 125k. SPR's @ 14,991'MD 7,020'TVD Mud weight 10.3 ppg. #1 pump 20 spm-640 psi 30 spm 910 psi.#2 pump,20 spm 730 psi,30 spm, 1080 psi. 12:00 14:30 2.50 15,601 15,742 PROD1 DRILL DDRL P Drill F/15,601'MD-T/15,742'MD TVD 7,008'. Flow rate 220 gpm, 2,450 psi,90 rpm,Torq on 13.5k off 11k, Flow out 35%, ECD-11.94. Bit weight 7k-10k,ADT/ART=2.05 hrs. Total bit-jar hrs=78.65. Up 185k, DN,65k, ROT 127k. SPR's @ 15,646'MD 7,015'TVD Mud weight 10.3 ppg. #1 pump 20 spm-610 psi 30 spm 990 psi.#2 pump,20 spm 650 psi,30 spm,960 psi. TD for well 15,742'MD. 14:30 16:00 1.50 15,742 15,742 PROD1 DRILL CIRC P Circulate Bottoms up 220 gpm, _2,300 psi,90 rpm,Torque 10.5k 16:00 18:00 2.00 15,742 15,742 PROD1 DRILL REAM P Backream F/15,742'MD-T/14,590' MD,220 gpm,2,300 psi, 90 rpm, Torque 10k-11k, Pulling speed 3 min per stand. Blow down top drive, Monitor well 15 min. Calculated fill ✓/ 8.1 bbl's Actual fill 17.8 bbl's. 18:00 19:00 1.00 15,742 15,742 PROD1 DRILL TRIP P Trip in hole F/14,509'MD-T/ 15,742'MD.Tripped on elevators, With no problems.Washed last stand to bottom. Calculated displacement 8.1 bbl's Actual displacement 4.75 bbl's. 19:00 23:00 4.00 15,742 15,742 PROD1 DRILL CIRC P Circulate 3 X bottoms up.220 gpm, 2,300 psi, 90 rpm,Torque 10.5k Losses while circulating 14 bbl's. 23:00 00:00 1.00 15,742 15,742 PROD1 DRILL OWFF P Monitor well for flow. Flow evident after 15 minutes flow was slight. Final flow check showed well static. 03/07/2011 Backream to shoe, Pump out to 5,567'MD, Pull on elevators to BHA, Lay down BHA, Lay down damaged Drillpipe. Rig up to Test Upper rams&annular. 00:00 09:00 9.00 15,742 8,862 PROD1 DRILL WASH P Pump out of hole F/15,651'MD-T/ 8,862'MD@ 2.7 BPM, 700 psi, Pulling speed 50 fpm, 195K up 75k down,Calculated fill 38.8 actual fill 54.8 09:00 10:00 1.00 8,862 8,862 PROD1 DRILL CIRC P Monitor well(Static)Circulate bottoms up @ 220 gpm, 1,900 psi. Reciprocate @ 40 rpm,4k torque. Page 34 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:30 0.50 8,862 8,391 PROD1 DRILL TRIP P Pull out on elevators F/8,862'MD- T/8,391'MD. Not taking correct fill. 10:30 14:30 4.00 8,391 5,567 PROD1 DRILL WASH P Pump out of Hole F/8,391 MD-T/ 7,827'MD.Attempted to pull on elevators F/7,827'MD-T/7,448'MD swabbing,Monitor well Static continued pumping out T/5,567'MD. Calculated fill 13.5 Actual fill 16.5. 14:30 17:30 3.00 5,567 402 PROD1 DRILL TRIP P Trip out on elevators to BHA.(402') Monitored well 20 min every 10 stands. (Static)Calculated fill 34.52 actual fill 35.25. 17:30 21:30 4.00 402 0 PROD1 DRILL PULD P Lay down BHA Remove sources, Download MWD data, Lay down remaining BHA, 21:30 23:00 1.50 0 0 PROD1 DRILL PULD P Lay down 3 stands of damaged drillpipe. ***Note 3 stands of drillpipe found with severly worn tool joints. The tool joint were worn evenly with out showing any specific area with a flat spot. 1 tool joint gauge 1/2" undergauge worn evenly in a circular pattern. ***Pick up 9 joints from pipeshed rack back in derrick. Pipe Drifted. 23:00 00:00 1.00 0 0 PROD1 WHDBO BOPE P Rig up to test 3-1/2"X 6"upper variable pipe rams and annular. 03/08/2011 Test Upper 3-1/2"X 6"Variable rams&Annular. RU to run 3-1/2"9.3 ppf L-80SLHTliner. PJSM, Run liner to 7041',por pal mix in liner top, circ liner volume with 1 stand of 4"dp made up, run liner on 4"to the 7"shoe @ 8869',circ 82 bbls, con't to run liner to 15701', make a top drive connection on stand#93,tag bottom,pick up to 185k(PU wt),then 10 more feet to 15738.51'. Break circulation pumping 4 bpm w/1500 psi. Shut down pumps, pick up to a connection, break connection,drop a 29/32"ball,make up connection, pump ball down @ 4 bpm w/1350 psi initial,final 1 bpm w/400 psi. Ball on seat after pumping 77 bbls total volume. 00:00 01:30 1.50 0 0 PROD1 WHDBO BOPE P Test Upper pipe rams 3-1/2"X 6" variables 250 psi low, 3,500 psi high, 5Q9 Test annular 250 psi low, 2,500 psi high.All test 5 min and charted. Tested with both 3-1/2"and 4"test joints. Rig down from test. Install wear bushing. 01:30 03:00 1.50 0 0 COMPZ DRILL RURD P Rig up to run 3-1/2"Production liner. 03:00 03:30 0.50 0 0 COMPZ DRILL SFTY P Pre job saftey meeting on running 3-1/2"lower completion. 03:30 12:30 9.00 0 5,977 COMPZ DRILL RUNL P Run 3-1/2"SLHT 9.3 ppg L-80 liner per the detail to 5977'.Obtain PU and SO wt's per rig engineer. Calculated displacement 18 bbls, actual 15.75 bbls. 12:30 14:00 1.50 5,977 7,040 COMPZ DRILL RUNL P Continue to run 3-1/2"SLHT 9.3 ppg L-80 liner per the detail f/5977'to 7040'. Obtain PU and SO wt's per rig engineer. Page 35 of 41 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:00 15:15 1.25 7,040 7,040 COMPZ DRILL RUNL P Make up Baker Flexlock III Liner Hanger and 5"x 7"ZAP liner top packer. Pour Pal mix in top of hanger,allow to set up. PU wt 85k, SO wt 69k. 15:15 16:00 0.75 7,040 7,140 COMPZ DRILL CIRC P Make up a stand of 4"XT39 drill pipe, RIH. Beak circulation @ 7140'. Circulate liner volume of 62 bbls @ 5 bpm w/1250 psi. PU wt 88k,SO wt 70k. 16:00 17:00 1.00 7,140 8,869 COMPZ DRILL RUNL P Continue to run 3-1/2"SLHT 9.3 ppg L-80 liner on 4"drill pipe f/7140'to the shoe @ 8869'. Obtain PU and SO wt's per rig engineer. 17:00 17:30 0.50 8,869 8,869 COMPZ DRILL CIRC P Circulate a string volume of 82 bbls, pumping 4.5 bpm w/1250 psi. 17:30 22:45 5.25 8,869 15,701 COMPZ DRILL RUNL P Continue to run 3-1/2"SLHT 9.3 ppg L-80 liner on 4"drill pipe.Obtain PU and SO wt's per rig engineer. Run from 8869'to 15701'(92 stands of 4" dp). 22:45 23:30 0.75 15,701 15,755 COMPZ DRILL RUNL P Make a top drive connection on stand#93. PU wt 185k, SO wt 90k. Run in the hole and tag bottom w/51' in on stand#93(15755.51'). Pick up full PU wt of 185k(7.5'stretch), continue to pick up 10'above TD to 34'in on stand 93(15738.51'). Break circulation ,pumping 4 bpm w/1500 psi-40%Totco flow out.Calculated displacement 67.68 bbls, actual 56.25 bbls. 23:30 00:00 0.50 15,755 15,738 COMPZ DRILL CIRC P Pick up to a tool joint.Shut down pumps, break connection,drop 29/32"ball, make connection back up,slack off to 44'in on stand (15748.51'),then pick up to 34' (15738.51'). Pump the 29/32"ball down:45 bbls @ 4 bpm w/1350 psi,then 22.5 bbls @ 3 bpm w/1100 psi,then 7.5 bbls @ 2 bpm w/650 psi,then 1 bpm w/ 400 psi until ball was on seat after pumping 77 bbls total. Note: Daily fluid losses 11 bbl,total to the well 276 bbls. Page 36 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/09/2011 24 hr Summary Pressure to 2400 psi to set liner hanger,then set down 45k to verify set. Pressure to 3500 psi to release liner,bleed pressure to zero. PU to verify w/150k PU wt. Pressure up to 4000 psi to blow ball seat. Clear dog sub f/top of liner tie back,slack off 40k to set liner top packer, PU then rotate 25 rpm w/6k ft lbs of torque, slack off and set 50k on liner top.Test to 3500 psi f/5 min. Bleed off press, PU while pumping to clear liner top. PU wt 145k.SO wt 110k.3-1/2"shoe @ 15742.01', liner top @ 8700.95'. Set back stand#93, LID a single of 4"dp.Monitor well-static.Circ bottom's up, pumping 6 bpm w/1300 psi. Blow down lines. Choke and kill and mud lines. PJSM, Slip and cut drill line. POOH laying down Weatherford 4"drill pipe f/8690'to Baker running tools. Pulling slow to avoid swabbing well. Monitor well on the trip tank.Calculated 49.6 bbls,actual 49.5 bbls. Clear and clean rig floor. PU completion running tools. PU control line spooler and equipment to the floor. PJSM on running 3-1/2"9.3 ppf L-80 EUE-m tubing completion. Run 3-1/2"9.3 ppf L-80 EUE-m completion per detail to 5798'.Obtain PU&SO wt's per Rig engineer. Monitor well on the trip tank. PU wt 75k,SO wt 65k. 00:00 01:00 1.00 15,738 15,742 COMPZ DRILL PACK P Pressure to 2400 psi to set liner hanger,then set down 45k to verify set. Pressure to 3500 psi to release liner, bleed pressure to zero. PU to verify w/150k PU wt. Pressure up to 4000 psi to blow ball seat. Clear dog sub f/top of liner tie back,slack off 40k to set liner top packer, PU then rotate 25 rpm w/6k ft lbs of torque, slack off and set 50k on liner top. Test to 3500 psi f/5 min. Bleed off press, PU while pumping to clear liner top. PU wt 145k.SO wt 110k. 3-1/2"shoe @ 15742.01', liner top @ 8700.95'.Will locate @ 8712.58' inside of top of liner. 01:00 01:15 0.25 15,742 8,690 COMPZ DRILL TRIP P Set back stand#93, lay down a single of 4"dp. 01:15 01:30 0.25 8,690 8,690 COMPZ DRILL OWFF P Monitor well-static. 01:30 02:15 0.75 8,690 8,690 COMPZ DRILL CIRC P Circulate bottom's up,pumping 6 bpm w/1300 psi. 02:15 02:30 0.25 8,690 8,690 COMPZ DRILL OTHR P Blow down lines. Choke and kill and mud lines. 02:30 02:45 0.25 8,690 8,690 COMPZ RIGMN1SFTY P PJSM on cutting 1-1/4"drilling line. 02:45 03:30 0.75 8,690 8,690 COMPZ RIGMNT SVRG P Slipped and cut 55'of 1-1/4"drill line. Check crown o matic. 03:30 12:00 8.50 8,690 3,670 COMPZ DRILL TRIP P Pull out of the hole laying down Weatherford 4"drill pipe f/8690'to 3670'. Pulling slow to avoid swabbing well. Monitor well on the trip tank. 12:00 15:30 3.50 3,670 0 COMPZ DRILL TRIP P Continue to pull out of the hole laying down Weatherford 4"drill pipe f/ 3670'to Baker running tools. Pulling slow to avoid swabbing well. Monitor well on the trip tank. Calculated 49.6 bbls,actual 49.5 bbls. Baker dog sub indicated packer was set. 15:30 16:00 0.50 0 0 COMPZ DRILL PULD P Clear and clean rig floor. 16:00 17:00 1.00 0 0 COMPZ RPCOM RURD P Pick up tubing running tools to the floor. Pick up control line spooler and equipment to the floor. Make up crossover to floor safety valve. Page 37 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on running 3-1/2"9.3 ppf L-80 EUE-m tubing completion. 17:30 00:00 6.50 0 5,798 `COMPZ RPCOM RCST P Run 3-1/2"9.3 ppf L-80 EUE-m completion per detail to 5798'(jt# 180 in the hole).Obtain PU&SO wt's per Rig engineer. Monitor well on the trip tank. PU wt 75k,SO wt 65k. 03/10/2011 Run 3-1/2"9.3 ppf L-80 EUE-m completion per detail to 6680'(jt#208 in the hole). MU 3-1/2"TMAXX-5E SSSV. RU Camco/Schlumberger spooler unit,test line-OK. Con't running 3-1/2"compl w/control line w/ 6200 psi on line holding valve open. Install SS bands(see detail). Run joints#209 to#269 in the hole f/6680' to 8621'.Change elevators f/3-1/2"YT to 4"dp. MU a 4"XT39 box x 3-1/2"EUE pin X-O. Make a top drive connection on a stand in the derrick. Pump while strapping in the hole f/location of seals and no go of locator sub. Pump 1 bpm w/250 psi. Make another connection, pump in the hole the same.Seals located w/116' in (8737.34'mule shoe depth). Shut down pumps, open bleeder. Continue to slack of and locate w/baker locator @ 134.5'(8755.84'mule shoe depth). POOH w/a stand, rack back in the derrick. Make a TD connection, PU until mule shoe was above the top of the liner @ 8700.95'. Pump down the tubing @ 5 bpm w/800 psi. Pump 37.5 bbls of 10.1 ppg vis spacer w/Flozan, pump 313.6 bbls of 10.3 ppg CaC12/NaCl, follow w/76 bbls of inhibited CaCl2(1%CRW-132),then 81 bbls 10.3 ppg CaC12/NaC1 brine to spot inhibited brine to the annulus. POOH stand of 4"dp. MU 4-1/2"IBT x 3-1/2"EUE crossover,two 4-1/2"pup joints,then 2 joints of 4-1/2"IBT-m tubing, install bushing puller-pull wear bushing.MU FMC hanger,terminate Camco control line.Test line to 5000 psi f/10 min-OK. RIH, RILDS,torque to 450 ftlbs.Set TWC, RU to test hanger-no test, back out LDS, Pull hanger to floor,change out hanger to one w/elastomer seal,connect control line,test line, RIH, RILDS,test hanger to 250 psi low f/5 min,5000 psi f/10 min-good test.Test tubing to 3500 psi,test annulus to 3500 psi-both good(all tests charted), shear DCK-2 valve in lower GLM, set TWC,test to 2600 psi-good.Clear floor, PJSM, ND BOPE, NU FMC tree. 00:00 00:30 0.50 5,798 6,680 COMPZ RPCOM RCST P Run 3-1/2"9.3 ppf L-80 EUE-m completion per detail to 6680'(jt# 208 in the hole). Obtain PU&SO wt's per Rig engineer.Monitor well on the trip tank. PU wt 83k,SO wt 72k. 00:30 02:00 1.50 6,680 6,680 COMPZ RPCOM RURD P Make up 3-1/2"TMAXX-5E SSSV (PN 100469229,ser#CZS-0086). Rig up Camco/Schlumberger spooler unit, hang sheave in derrick,connect 1/4"control line, pressure to 6200 psi, monitor f/5 minutes after stablized-OK. 02:00 04:30 2.50 6,680 8,621 COMPZ RPCOM RCST P Continue running 3-1/2"completion w/control line w/6200 psi on line holding valve open. Install 5/8" stainless steel bands on each joint above the box plus one on the SSSV neck and one on the pup joint above the SSSV.A total of 63 bands in the hole at this point. Run joints#209 to #269 in the hole f/6680'to 8621'. 04:30 04:45 0.25 8,621 8,621 COMPZ RPCOM RURD P Change elevators f/3-1/2"YT to 4" dp. Page 38 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:45 1.00 8,621 8,756 COMPZ RPCOM TRIP P Make up a 4"XT39 box x 3-1/2"EUE pin crossover. Make a top drive connection on a stand in the derrick. Pump while strapping in the hole f/ location of seals and no go of locator sub. Pump 1 bpm w/250 psi. Make another connection, pump in the hole the same. Seals located w/116'in (8737.34'mule shoe depth).Shut down pumps,open bleeder. Continue to slack of and locate w/baker locator @ 134.5'(8755.84'mule shoe depth). PU wt 110k, SO wt 75k. 05:45 06:00 0.25 8,756 8,700 COMPZ RPCOM TRIP P Pull out of the hole w/a stand, rack back in the derrick. Make a top drive connection,pick up until mule shoe was above the top of the liner @ 8700.95'. 06:00 08:45 2.75 8,700 8,700 COMPZ RPCOM CIRC P Pump down the tubing @ 5 bpm w/ 800 psi. Pump 37.5 bbls of 10.1 ppg vis spacer w/Flozan, pump 313.6 bbls of 10.3 ppg CaCl2/NaCl,follow w/76 bbls of inhibited CaCl2(1% CRW-132),then 81 bbls 10.3 ppg CaCl2/NaCl brine to spot inhibited brine to the annulus. 08:45 09:00 0.25 8,700 8,621 COMPZ RPCOM TRIP P Pull out of the hole w/stand of 4"drill pipe and crossover. Rack back stand of drill pipe. 09:00 10:00 1.00 8,621 8,728 COMPZ RPCOM HOSO P MU 4-1/2"IBT x 3-1/2"EUE crossover,two 10'4-1/2"pup joints, then 2 joints of 4-1/2"IBT-m tubing, install FMC bushing puller-pull wear bushing. 10:00 12:00 2.00 8,728 8,753 COMPZ RPCOM HOSO P Make up FMC hanger w/metal to ✓ metal seal,terminate Camco control line.Test connections to 5000 psi f/ 10 minutes-OK. Run in the hole and land hanger. Run in lockdown screws,torque to 450 ft lbs. Calculated displacement 27 bbls, actual 25.25 bbls. PU wt 112k, SO wt 75k. Used a total of 66 stainless steel bands 5/8". 12:00 13:30 1.50 8,753 8,753 COMPZ RPCOM HOSO P Lay down landing joint. Set TWC, Install Landing joint. RU to test hanger seal-no test. Lay down landing joint, pull TWC. 13:30 14:30 1.00 8,753 8,728 COMPZ RPCOM TRIP T MU landing joint. Back out LDS, Pull hanger to floor,disconnect control line. Lay down hanger w/metal to metal seal. 14:30 15:30 1.00 8,728 8,753 COMPZ RPCOM PRTS T MU new hanger w/elastomer seals, reconnect control line,test to 5200 psi f/5 min-OK, pressure to 6200 psi to maintain flapper valve open, hold pressure f/10 minutes then shut in. RIH, RILDS,torque to 450 ft lbs. Page 39 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:00 1.50 8,753 8,753 COMPZ RPCOM PRTS T Lay down landing joint A, PU landing joint B, Rig up to test hanger seals w/test pump.Test to 250 psi low f/5 minutes,then 5000 psi high f/10 minutes. Chart test. Rig down testing equipment. Pull landing joint and TWC. 17:00 19:30 2.50 8,753 8,753 COMPZ RPCOM PRTS P Pump down the IA(7"x 3-1/2")to confirm seals in the seal bore extension.Test to 1000 psi f/10 minutes-OK.Chart test. Bleed off pressure. Drop ball and rod assembly down the tubing.With IA open to atmosphere,test tubing to 3500 psi f/30 minutes, chart test- good. Bleed tubing to 1800 psi,then pressure the annulus to 3500 psi f/ 30 minutes, chart test-good. Bleed off the IA,then bleed of the tubing and leave open to flow line. Pressure up on the IA to shear the DCK-2 vlave in the lower GLM @ 8373'. Sheared at 2525 psi as expected. Bleed pressure to zero. 19:30 20:00 0.50 8,753 0 COMPZ RPCOM PRTS P Lay down the landing joint, set TWC. Test the TWC by pumping down the IA and testing against the ball and rod and the TWC.Test to 2600 psi f/ 10 minutes,chart test-good. Bleed off the pressure. 20:00 21:30 1.50 0 0 COMPZ RPCOM PULD P Clear rig floor of all completion running tools. 21:30 21:45 0.25 0 0 COMPZ WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 21:45 23:00 1.25 0 0 COMPZ WHDBO NUND P Nipple down BOPE. 23:00 00:00 1.00 0 0 COMPZ WHDBO NUND P Nipple up FMC tree. 03/11/2011 Nipple up FMC tree,test hanger void to 5000 psi f/10 minutes-good, rig up/test tree to 5000 psif/10 minutes-good. Pull FMC two way check valve,apply 6000 psi to control line and open SSSV, rig up to freeze protect well. PJSM w/Little Red and crew. Little red pump 80 bbls of diesel down the IA taking returns to the rock washer. Initial pressure 500 psi,final while pumping 1700 psi,shut down pumps and pressure was 500 psi."U"tube IA to the tubing, pressure equalized to 200 psi,then increased to 300 psi after 1 hr. Shut in well, rig up FMC lubricator,set BPV.Tubing pressure was 325 psi. Secure well, rig down circulating hoses. Remove douuble valve f/the annulus. Rig up FMC lubricator,set BPV using lubricator.Well had 325 psi on tubing. Secure well. Rig down circulating hoses. Remove double valve from the annulus. Pre job safety meeting. Lay down 72 stands of 4"Weatherford dp f/the derrick via the mouse hole. Prepare rig to move f/ CD3-199 to CD3-198. Distance to move is 20'nominal(actual 19.47'). Rig released to move to CD3-199 @ 1500 hrs 3-11-2011. 00:00 00:15 0.25 0 COMPZ WHDBO NUND P Continue to nipple up FMC tree. 00:15 00:45 0.50 COMPZ WHDBO PRTS P Test FMC hanger void and lockdown screws to 5000 psi f/10 minutes. Witness of test by Rig supervisor. 00:45 01:15 0.50 COMPZ WHDBO RURD P Fill tree w/diesel, rig up to test tree. 01:15 01:30 0.25 COMPZ WHDBO PRTS P Pressure test tree to 5000 psi w/test pump.Chart test f/10 minutes. Page 40 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 COMPZ WHDBO PRTS P Pull two way check,then apply 6000 psi to control line and open the SSSV. 02:00 02:30 0.50 COMPZ DRILL RURD P Rig up to freeze protect well with diesel,using Little Red. 02:30 02:45 0.25 COMPZ DRILL SFTY P Pre job safety meeting on freeze protection. 02:45 04:00 1.25 COMPZ DRILL FRZP P Little Red pressure test lines to 2000 psi-good. Pump 80 bbls of diesel down the IA @ 1.5 bpm w/initial 500 psi,final 1700 psi while pumping. After shut down, pressure was 500 psi to depth of 3035'(2750'TVD). SIMOPS:Change out saver sub on the top drive f/4"XT39 to 4-1/2"IF. 04:00 06:00 2.00 COMPZ DRILL PRTS P Rig down Little red f/well.Start"U" tubing annulus to the tubing. Initial 500 psi. Pressure went to 200 psi, then started rising.After 1 hr _ pressure was 300 psi. 06:00 07:30 1.50 COMPZ WHDBOOTHR P Rig up FMC lubricator,set BPV using lubricator.Well had 325 psi on tubing.Secure well. Rig down circulating hoses. Remove double valve from the annulus. 07:30 12:45 5.25 COMPZ DRILL PULD P Pre job safety meeting. Lay down 72 stands of Weatherford 4"dp f/the derrick via the mouse hole. 12:45 15:00 2.25 COMPZ DRILL DMOB P Prepare rig to move f/CD3-199 to CD3-198. Distance to move is 20' nominal(actual 19.47'). Rig released to move to CD3-198 @ 1500 hrs 3-11-2011. Page 41 of 41 ` t • sugE A [LAsEA /sEANPARNELLGovERNoR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 T. Senden Wells Engineer ConocoPhillips Alaska, Inc. + O ( b P.O. Box 100360 a r Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-199 Sundry Number: 311-089 Dear Mr. Senden: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Se:mount, Jr. Chair DATED this 1 day of April, 2011. Encl. . STATE OF ALASKAP' __. ALASK, .AND GAS CONSERVATION COMMISSl A,It-(I �,,, _ft o?9�// APPLICATION FOR SUNDRY APPROVALS to' �A\ 20 AAC 25.280 k(' 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing f Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate - Alter casing Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17. Exploratory r 211-010 - 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20635-00- 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 CD3-199— 9.Property Designation(Lease Number): 10.Field/Pool(s): �o ..7-3e.,-4ADL 372104,372105. Colville River Field- / For.e I o., 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): 15472' 7008' 15472' 7008' none none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 114' 114' Surface 2630' 9.625" 2663' 2452' Intermediate 8835' 7" 8869' 6950' Liner 7041' 3.5" 15742' 7008' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5" L-80 8753' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) HRD ZXP Liner Top Packer 8701'MD,6926'TVD 9 TAM swell packers 8896,8974,9838, 10767,11880, 12346,12346,13396,14451,15472 MD 12.Attachments: Description Sunmary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory > Development )✓ Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/30/2011 Oil p-- Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: T.Senden©265-1544 Printed Nam T. Send n Title: Wells Engineer Signature l( 7L SR.1 i10e•\ Phone: 265-1544 Date -3/17/1i Commission Use Only Sundry Number:3 1 ('' Conditions of approval: Notify Commission so that a representative may witness RECEIVED cE'_ `D Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r MAR 2 3 2011 Other: Masks Oil&Gas Cons.Commission Subsequent Form Required: / .'0Y Anchorage APPROVED BY r Approved by: COMMISSIONER THE COMMISSION Date: 1 I 1 ( Form 1 d 1 S•30•(0 R I GINA', S mit in Duplicate °F �13i �1P B4 + �� Overview: CD3-199 was drilled and completed on March 11, 2011. A fracture stimulation is planned prior to putting the well on production. A 3-1/2" ported sleeve system was run in the openhole section with swell packers, Procedure: 1. MIRU sixteen clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 4000 ✓ bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 250 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 15-20 BPM with a maximum pressure of 4750 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment. • 300 bbls YF125ST Pad • 95 bbls YF125ST w/ 1 ppa 16/30 White Sand Igt$ • 95 bbls YF125ST w/2 ppa 16/30 White Sand Dy • 180 bbls YF125ST w/4 ppa 16/30 While Sand • 140 bbls YF125ST w/6 ppa 16/30 White Sand • 110 bbls YF 125ST w/7 ppa 16/30 White Sand • Drop ball and repeat 7 more times X- • Flush with linear fluid and freeze protect Total Sand: -800,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. e 7 WNS CD3-199 ConocoPhillips /" Well Attributes Max Angle&MD TD I Wellbore APWWI Field Name Well Status Inert MD(hKB) Act Bum(RKB)laSitta. 501032063500 FIORD NECHELIK PROD 91.91 15.678.89 15,742.0 Comment 625(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date •-" sFal Coma MORQONTAL.003.Ihv,a21.2Jn • 503`1:TRDP Last WO 28.00 3'11:2011 Scnemanc-AdmAnnotation Depth I965I End Date Annotation Last Mod..End Date rANc;EA,21 Last Tag Rev Reason Imosbor 3.21.2011 Casing Strings nif gr Casing Description String 0... String ID..Top(965) Set Depth(f...Set Depth(TVD)_. String Wt...String... String Top Thrd CONDUCTOR 16 15.250 31.0 114.0 114.3 6250 H-40 Welded Casing Description String 0... String ID...Top(MKS) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd SURFACE 95:8 8.835 26.5 2.662.8 2457.3 40.00 L-80 ETC-rn CONDUCTOR. I I Casing Description String 0... String ID..Top(h)(15) Set Depth(f...Set Depth(TVD)_. String Wt...String... String Top Thrd INTERMEDIATE 7 6.276 25.2 8.870.0 6.952.5 26.00 L-80 ETC-m 31-114 Casing Description String 0... String ID...Top(hK6) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd LINER 3112 2.992 8,700.9 15.742.0 9.30 L-80 SLHT SAFETY VLLv. _ i Liner Details Top Depth (TVD) Top Inc) Nom)... 11 Top(hK6) (RK8) (°) ken,Description Comment ID(in) 8.700.9 6.925.5 77.88 PACKER "HRD"ZXP Liner Top Packer 4.360 SURFACE, L 26-2.653 8.720.7 6.930.0 78.71 NIPPLE "RS"PackoR Nipple 4.260 8.723.5 6.930.6 78.83 HANGER Flex-Lock Liner Hanger 4.360 GAO LIFT, 3.508 8.734.8. 6.932.8 79.30 SEE Seal Bore Extension 4000 8.753.5 6.936.2 80.09 XO BUSHING Cross Over Bushing 2.937 8.890.5 6.952.3 82.71 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 8.968.6 6.962.8 85.12 Swell Packer Water Activated Assembly.TAM Swell Packer 2.960 • GAS LIFT, f- 9.419.0 6.975.0 88.66 FRAC PORT Ball Actuated Sleeve(2.000") 2.000 8%B 9.832.0 6.987.1 87.79 Swell Packer Water Activated Assembly.TAM Swell Pecker 2.960 10.313.2 6.994.3 91.78 FRAC PORT Ball Actuated Sleeve(1.875") 1.875 • GAS UFT, 10,760.9 6,993.3 89.82 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 5.373 x 11.303.3 6.997.5 89.49 FRAC PORT Ball Actuated Sleeve(1.750") 1.750 NIPPLE.8.516 • meee 11,874.7 7,0021 90.00 Swell Packer -Water Activated Assembly.TAM Swell Packer 2.960 12.108.0- 7,002.7 88.19 FRAC PORT Ball Actuated Sleeve(1.625") 1.625 LOCATOR. 12.340.1 7.007.5 89.61 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 5.711 12848.9 7,014.3 89.82 FRAC PORT Ball Actuated Sleeve(1.500") 1.500 I 13,390.7 7,027.8 88.24 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 13.904.1 7,025.1 90.51 FRAC PORT Ball Actuated Sleeve(1.375") 1.375 `EAL AB r 3 - 14,445.3 7,025.3 88.52 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 SEAL ASSY. _ 1 -1 14,959.8- 7,021.4 89.54 FRAC PORT Ball Actuated Sleeve(1.25-) 1.250 5 751 1 • 15,4664 7.015.3 90.75 Swell Packer Water Activated Assembly,TAM Swell Packer 2.960 Tubing Strings Tubing Description String 0... String ID...Top(hKB) Set Depth(f...Sat Depth(TVD)-.String Wt...String... String Top Thrd TUBING 3112 2.992 21.3 8.753.1 6.936.1 9.30 L-80 EUE-Brd-mod NTERr1 25.8 97. Completion Details 23.9 97 Top Depth (ND) Top Incl Nom)... Top(966) (RKB) 1°) Mm Description Comment ID(in) 21.3 21.3 -0.03 HANGER FMC 41/2"x 11"tubing hanger(10.85"OD) 4.500 ;: 130.2 130.2 0.47 XO-Reducing Crossover 4-1/2"12.6 ppf L-80 IBT-m box x 3-1/2"9.3 ppf L-80 EUE-m 2.992 Pill 2.056.7 1.992.1 35.49 SAFETY VLV '3.1 Cameo TRMAXX-5E w.'2812""X"profile,1/4"single control line 2.812 ■ •J '7 8.516,2- 6.869.7 66.96 NIPPLE 'HES"XN"nipple(2.813"profile 21275"No-go)w/RHC plug installed 2813 8,711.5 6.928.0 78.32 LOCATOR 'Baker 80-40 GBH locator 2.970 8.743.1 6,934.4 79.65 SEAL ASSY 80-40 Bonded Seal assembly 3.000 8,751.0 6,935.8 79.99 SEAL ASSY 80-40 Seal assembly w.'1/2 mule shoe 3.000 / Notes:General&Safety [.•J End Date Annotation 3,21!2011 NOTE:VIEW SCHEMATIC w'Alaska Schematic9.0 L■ ■J $ I . y Mandrel Details Top Depth Top Pon IND) Incl OD Valve Latch Size TRO Run Stn Top(RIO) (hK6) (`I Make Model Ilnl Mry Type Type (In) (psi) Run Date Com... 1 3,907.8 3.397.1 40.26 CAMCO KBMG1GASLIFT DMY BK-S 0.000 0.0 3 1012011 2 6,769.0 5.594.0 33.54 CAMCO KBMG1 GAS LIFT OMY BK-S 0.000 0.0.3110,2011 3 8.372.8 6,811.6 63.53 CAMCO KBMG 1 GAS LIFT SOV INT 0.000 O.0 3/1012011 TD.1'.7421a7 LINER. 5711-1`1742 HALLIBURTON I Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska March 14, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-199 AK-MW-0007896022 CD3-199 50-103-20635-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 B iq .com ?I, :."..ea, Si ned: l �, c 0 —0 ( 6 Page 1 of 1 v r -r Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 03, 2011 10:33 AM To: 'Robertson, Ryan G' Cc: Regg, James B (DOA) Subject: RE: CD3-199 Update (PTD 211-010) Ryan, I believe that is all the information we require. Thanks for the followup ... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Thursday, March 03, 2011 10:03 AM To: Schwartz, Guy L (DOA) Subject: CD3-199 Update (PTD 211-010) Guy, A quick update on the CD3-199 well... The rig crews were able to circulate and kill the influx taken yesterday while drilling the CD3-199 lateral hole. The final mud weight used to control the well was 10.3 ppg. Once circulated around, the well was static for 30 minutes. Our rig site supervisors have been in touch with the AOGCC on the slope regarding this matter. It is understood that when the drilling BHA is pulled from the hole, the upper pipe rams and annular preventer will be pressure tested. The AOGCC slope reps will be contacted at least 24 hours in advance of this test. Drilling of the 6.125" lateral hole is currently ongoing at 12,191' MD. Please let me know if you require additional information regarding the well control event described above. Ryan Drilling Engineer I Conoco0nilllps Alaska Direct,(9071265-6318 I Mobile (907)980-5107 3/3/2011 IIJ Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, March 02, 2011 5:08 PM To: Schwartz, Guy L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: CD3-199 - Use of BOPE to Prevent the Flow of Fluids(PTD 211-010) Guy, On March 2nd, 2011 at approximately 12:50 PM, the BOPE on Doyon 141 was used to contain a fluid influx into the CD3-199 lateral wellbore (PTD—211010). This well is being drilled by ConocoPhillips Alaska at the Alpine field. During lateral drilling operations at 11,960' MD/7,000' TVD, a 5 bbl influx of fluid was taken during a connection. At the time of drilling operations, the wellbore fluid weight was 9.8 ppg. To control the fluid influx, the upper pipe rams were closed on the drillpipe. The BOP equipment was last tested on February 24th, 2011. After shutting in the well and allowing it to stabilize, the pressure on the drillpipe and casing was 110 psi. The plan forward is to weight and kill the well. Once the well has been killed and proven to be static, drilling operations will resume. Please contact me if you require any additional information, Ryan Drilling Engineer j ConocoPhillips Alaska Direct (907)265-6318 Mobile (907)980-5107 3/3/2011 871 [E OT SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-199 ConocoPhillips Alaska, Inc. Permit No: 211-010 Surface Location: 3893' FNL, 661' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 1974' FNL, 2737' FEL, SEC. 09, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to 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, 0,11 Daniel T. Seamount, Jr. 5-74 Chair DATED this I day of February, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) lr -1' STATE OF ALASKA :NG: jALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL "'€ j �' �? Boras. - ssion 20 AAC 25.005 'iilLrafraan 1 a.Type of Work: lb.Proposed Well Class: Development-Oil Q Service-Winj ❑ Single Zone Q • 1 c.Specify if well is proposed for: Drill Q • Re-drill❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 . CD3-199 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 15774' TVD: 7027' Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): ,i 3893'FNL,661'FEL,Sec.5,T12N, R5E, UM ADL 372104,372105,371> i Zy Fiord Oil Pool • / Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1698'FNL, 1529'FEL,Sec. 5,T12N, R5E, UM LAS2112 2/5/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1974'FNL,2737'FEL,Sec.9,T12N, R5E, UM 2560 +/-4.0 miles to ADL 391451 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 40.8 feet 15.Distance to Nearest Well Open Surface:x- 388383.5 ' y- 6003878.8 Zone- 4 GL Elevation above MSL: 12.8 feet to Same Pool: CD3-121 ,2100' 16.Deviated wells: Kickoff depth: 242 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89.6° deg Downhole:3289 psig • Surface:2589 psig • 18.Casing ProSram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length s MD ND MD ND (including stage data) 24" 16" 62.5 H-40 Welded 77 37 37 114 114 Pre Installed 12.25" 9.625" 40 L-80 BTC 2613 37 37 2650 2450 446 sx AS Lite 3,230 sx 15.8'G' ✓ 8.75" 7" 26 L-80 BTC-M 8833 37 37 8870 6961 1st-215 sx 15.8'G' 2nd-185 sx 15.8 G ✓ 3.5" 9.3 L-80 EUE 8528 32 32 8560 6959 Tubing •' 6.125" 3.5" 9.3 L-80 IBT-M 7260 8500 6868 15760 7027 Liner with Swell PKRS and SS for Frac 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: OA 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson 265-6403 Printed Name Chip Alvord Title Alaska Drilling Manager Signature4(._ak Phone 265-6120 Date t((((Leiit Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: /�')L � �^Lc° Date:at, \ k for other requirements Conditions of approval: If box is checked,well mea not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales: 13500 X93 - oar 'ie-s1.--- S mples req'd: Yes El No No Mud log req'd: Yes ❑ No El/Other: -2Spa/5.: Aetnu.(4 r (t.1 C" IIkS measures: Yes ❑ No g Directional svy req'd: Yes I2( No ❑ c AA-Adz a 3 SS O k)C z.) , / / • - /� APPROVED BY THE COMMISSION ` DATE: �,`� �, � ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) d , /'ubmit in Duplicate,.// 2c/, c, ConocoPhillips Alaska, Inc. lorr Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhilhps Telephone 907-276-1215 Jan 18th, 2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 () ()) Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-199 Aissk6 b OnS. ': iSSlon lincoorage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 • (Fiord) pad. The intended spud date for this well is February 5th, 2010. It is intended that Doyon Rig 141 be used to drill the well. CD3-199 will be completed as a horizontal producer in the Nechelik reservoir. The well will be flowed back to - mitigate reservoir damage and then hooked up to begin production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 7th winter season of drilling on the Fiord pad and there has not been a significant indication of shallow gas ' or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling I collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265-6403, or Liz Galiunas at 265-6247. Sincerely, /4/ o L, Nina Anderson Drilling Engineer Attachments cc: CD3-199 Well File/Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Mike A. Winfree ATO 1704 Lanston Chin Kuukpik Corporation CD3-199 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000'TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned • wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density(ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density(ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers • ORIGINAL Fiord Nechelik : CD3-199 Procedure 1. Move Doyon 141 on CD3-199, dewater cellar as needed. 2. Rig up riser. (Jo p'. ) i 3. Drill 12-1h" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 9-5/8"surface casing. 5. Install and test BOPE to 3500 psi high and 250 psi low. / 6. Pressure test casing to 2500 psi. 7. Pick up and run in hole with 8-3/4"drilling BHA. Drill out 20' of new hole. Perform leak off test. • 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) • 9. Run and cement 7" casing as per program. If needed, a second stage cement job will be pumped to isolate the K2. (Qannik)formation. go je,4At5 7cst- 10. Perform a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 3500 psi high and 250 psi low. 12. PU and RIH with 6-1/8"drilling assembly. Pressure test casing to 3500 psi. 13. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 14. Displace well to Flo-Thru drilling fluid. 15. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Dens/Neut). • 16. Circulate the hole clean and pull out of hole. 17. Run lower completion of 3-1/2"liner and liner hanger with 8 stage Frac Sleeve system. 18. Run upper completion: 344, 9.3#, L-80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. 19. Drop ball and rod to set packer. Displace drilling fluids with brine/diesel. , 20. Sting in, space out, and land hanger. 21. Install 2 way check and pressure test hanger seals to 5000 psi. Pull TWC. 22. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 23. Install TWC and pressure test through SOV to 1000 psi in the direction of flow. Nipple down BOP."" 24. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Set BPV and secure well. Move rig off. V KIEL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-302 is the closest existing well with a clearance factor less than 2.0. Ellipse to ellipse separation is 7.33' @ 762' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faultingwithin the Nechelik r ry it • ese o section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-199 will be injected into a permitted annulus on CD3 pad or the class 2/class 1 disposal well on CD1 pad. The CD3-199 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, potential Kuparuk reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Upon completion of CD3-199 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure= (12.0 ppg) *(0.052) *(Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) *(0.052) *(2450') + 1,500 psi = 3028 psi Pore Pressure = 1,108 psi Therefore Differential = 3028— 1108 = 1920 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi R ! G1NAL DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8 surface casing casing point—8 3/4" Section—6 1/8 /4 1/8" point— 12 ,, Density 8.6— 10.0 ppg 9.6—9.8 ppg 9.0-9.3 ppg PV 6— 16 10—15 YP 30—60 11 — 19 25—30 Funnel Viscosity 70—300+ Initial Gels 8 - 10 10— 15 10 minute gels <20 12 -20 API Filtrate NC— 10 cc/30 min 5— 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5-9.0 9.0- 10.0 9.0-9.5 V KCL 3 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain • mud weight< 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill-in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. iIG1NAL Completion Schematic Colville River Field CD3-199 Nechelik Production Well Completion Updated 1/17/2011 Sperry Drilling Services CD3-199wp07 ,16"Conductor to 114' Page 1 of 2— Upper Completion Packer Fluid mix: Inhibited Kill weight 6%KCI Brine __.ag,.. with 2000'TVD diesel cap 9-5/8"40 ppf L-80 BTC Mod i 1111 Surface Casing @ 2650' MD/2450'TVD Upper Completion MD ND 6 GL J cemented to surface 1)Tubing Hanger 36' 36' 2)4-%"12.6#/ft IBT-Mod Tubing(2 its),XO TOC @+1- 3)3-'/2'9.3#/ft L-80 EUE-Mod Tubing • 4285' MD/3683'TVD 4)Camco TRMAXX-5E SSSV(2.812"ID) 2062' 2000' r with control line to surface. Qannik Interval Cannon Cross-coupling clamps on every joint F ; Top+/- 4785' MD/4061'TVD 5)3-''/z"9.3#/ft L-80 EUE-Mod Tubing • O Q 6)3-W x 1"Camco KBMG GLM w/DV 3909' 3400' 7)3-'/z'9.3#/ft L-80 EUE-Mod Tubing ES Cementer 8)3-W x 1"Camco KBMG GLM wl DV 6779' 5600' +/-5311' MD/ 9)3-'/2'9.3#/ft L-80 EUE-Mod Tubing 4458'TVD 10)Camco KBMG GLM(2.867"ID)w/DCK2 8360' 6707' Pinned for 2500 psi casing to tbg shear 11)3-'/z'9.3#/ft P-110 EUE-mod Tubing 12)HES XN 2.813"(2.75"NoGo)-with RHC Plug 8500' 6868' 13)3-W 9.3#/ft P-110 EUE-mod Tubing joints 14)BOT Stinger w/Fluted WLEG stinger 8560' 6959' 8 GL J 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope TOC Calculated @+/-7810' MD/6473'TVD CO 0 (300'above Packer&500' MD logo above Kuparuk) • 'I:I' 14 iii iii iii III 1111 III II IIII Top Kuparuk C ® I I -C -V -C -C -) -C 4. D 8310' MD/6,785'TVD Top Nechelik 7"26 ppf L-80 BTC Mod from 36'to 8400' MD/6827'TVD 6-1/8"Hole TD at 8870 MD/6,961'TVD 7"26 ppf P-110 BTC Mod from 8400' MD to 8870'MD/6961'TVD at 15774'MD/ 7,027'TVD / ORIGINAL Lower Completion: Colville River Field CD3-199 Nechelik Production Well Completion Updated 1/17/2011 "1s°Conductor to 114' Sperry Drilling Services CD3-199wp07 Packer Fluid mix: Page 2 of 2- Lower Completion Inhibited Kill weight Lower Comoletion IXQ 6%KCI Brine 15)Baker 5"X 7"Flex Lock Hanger w/Sealbore Extension 8500" 6868' with 2000'TVD 16)X0 5"Hydril 521 X 3-%"SLHT diesel cap 17) A" 9.3#/ft,SLHT Tubing 0.i 3-18)3-%"x 6-A"Centralizers SLHT Box x Box 19)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD 9-5/8"40 ppf L-80 BTC-Mod 20)3-%"x 6-1/"Centralizers SLHT Box x Pin J 6,, Surface Casing 21)3-1/2",9.3#/ft,SLHT Tubing @ 2650'MD/2450'TVD 22)3-h"SLHT Ball Actuated Sleeve(2.000"Seat ID)(2.125"Ball) TBD TBD 23)3-1/2",9.2#/ft,SLHT Tubing 6 GL cemented to surface 24)3-W x 6-W Centralizers SLHT Box x Box 25)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD TOC @+/- 26)3-W x 6-1/2"Centralizers SLHT Box x Pin 27)3-1/",9.3#/ft,SLHT Tubing 4285' MD/3683'TVD 28)3-W SLHT Ball Actuated Sleeve(1.875"Seat ID)(2.000"Ball) TBD TBD 29)3-%",9.3 Mt,SLHT Tubing 30)3-1/,"x 6-1/2"Centralizers SLHT Box x Box Qannik Interval 31)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD Top+/- 4785' MD/4061'TVD 32)3-1/2"x 6-1/2"Centralizers SLHT Box x Pin S D 033)3-1/,",9.3#/ft,SLHT Tubing ES Cementer 34)3-W SLHT Bat Actuated Sleeve(1.750"Seat ID)(1.875"Ball) TBD TBD 35)3-1/2",9.3#/ft,SLHT Tubing +/-5311'MD/ 36)3-'/"x 6-h"Centralizers SLHT Box x Box 4458'TVD 37)Swell Packer(3-1/2"SLHT)OD 6.38"w/10'sealing element TBD TBD 38)3-W x 6-W Centralizers SLHT Box x Pin 39)3-1/2",9.3#/ft,SLHT Tubing 40)3-1/2"SLHT Bat Actuated Sleeve(1.625"Seat ID)(1.750"Bat) TBD TBD 41)3-1/2",9.3#/ft,SLHT Tubing 42)3-11:"x 6-14"Centralizers SLHT Box x Box 43)Swell Packer(3-14"SLHT)OD 6.38"w/10'sealing element TBD TBD 8 GL j 44)3-114"x 6-114"Centralizers SLHT Box x Pin 45)3-1/:",9.3#/ft,SLHT Tubing 3-1/2" 9.3 ppf L-80 EUE M 46)3-11:"SLHT Ball Actuated Sleeve(1.500"Seat ID)(1.625"Ball) TBD TBD tubingrun with Jet Lube 47)3-1/:",9.3#/ft,SLHT Tubing 48)3-1/:"x 6-114"Centralizers SLHT Box x Box Run'n'Seal 49)Swell Packer(3-1/:"SLHT)OD 6.38"w/10'sealing element TBD TBD pipe dope 50)3-114"x 6-14"Centralizers SLHT Box x Pin 51)3-114",9.3#/ft,SLHT Tubing 52)3-114"SLHT Ball Actuated Sleeve(1.375"Seat ID)(1.500"Bat) TBD TBD' 1 53)3-1/2",9.3#/ft,SLHT Tubing 54)3-1/:"x 6-1/:"Centralizers SLHT Box x Box TOC Calculated 55)Swell Packer(3-W SLHT)OD 6.38"w/10'sealing element TBD TBD -7810'MD/6473'TVD 56)3-1/2"x 6-W Centralizers SLHT Box x Pin +/- 57)3-W,9.3#/ft,SLHT Tubing (300'above Packer&500' MD 58)3-14"SLHT Bat Actuated Sleeve(1.250"Seat ID)(1.375"Ball) TBD TBD UP TISSi above Kuparuk) 59)3-1/2",9.3#/ft,SLHT Tubing 60)3-1/:"x 6-14"Centralizers SLHT Box x Box 61)Swell Packer(3-14"SLHT)OD 6.38"w/10'sealing element TBD TBD 62)3-1/2"x 6-14"Centralizers SLHT Box x Pin 63)3-1/2",9.3#/ft,SLHT Tubing 64)3-1/2",9.3#/ft,SLHT Pre-Perforated Pup TBD TBD 65)3-1/2",9.3#/ft,SLHT Tubing 66)3-%"SLHT Orange Peel 15760' 7027" ® ' ■ _ iii_ ■ nil _ ■ _ ■ _ ■ osa Top Kuparu\p„.:: �r11\ a 8310'MD/6,785'TVD . . . . .0 .G El . . . ■ ■ Top Nechelik 7"26 ppf L-80 BTC Mod from 36'to 8400'MD/6827'TVD 6-1/8" Hole TD at 8870 MD/6,961'TVD 7"26 ppf P-110 BTC Mod from 8400' MD to 8870'MD/6961'TVD at 15774'MD/ 7,027'TVD Y ORIGINAL CD3-199 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 9 5/8 2650/2450 14.5 1109 1602 7" 8870/6961 16.0 3150 2589 N/A 15774/7027 16.0 3289 ** N/A • NOTE: The Doyon 141 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. • ** NOTE: Pore Pressure for production interval is estimated reservoir pressure PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) -0.1]D Where: ASP=Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP= [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 114 = 53 psi OR ASP= FPP—(0.1 x D) = 1109—(0.1 x 2450') = 864 psi 2. Drilling below surface casing (9 5/8") ASP= [(FG x 0.052)—0.1] D = [(1O4..5 x 0.052)—0.1] x 2450= 1602 psi ✓ ASP= FPP—(0.1 x D) = 3150—(0.1 x 6961') =2454 psi 3. Drilling below intermediate casing (7") ASP= Reservoir Pressure—(0.1 x D) = 3289—(0.1 x 7027') =2589 psi I :' Cementing Program: 9 5/8" Surface Casing run to 2650' MD/2450' TVD. Cement from 2650' MD to 2150' (500' of fill)with Class G +Adds @ 15.8 PPG, and from 2150' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1555' MD). Lead slurry: (2150'-1555')X 0.3132 ft3/ft X 1.5 (50% excess) =279.5 ft3 below permafrost 1555' X 0.3132 ft3/ft X 3.5 (250% excess) = 1704.6 ft3 above permafrost Total volume = 279.5 + 1704.6 = 1984.1 ft3 => 446 Sx @ 4.45 ft3/sk System: 446 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50%excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft= 34.7 ft3 shoe joint volume Total volume =234.9 + 34.7 =269.6 ft3 =>230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3%D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8870' MD/6961' TVD: Cemented in two stages Cement from 8870' MD to 7810' MD (300' MD above the packer& minimum 500' MD above top of Kuparuk reservoir)with Class G+ adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (8870' -7810') X 0.1503 ft3/ft X 1.4 (40% excess) = 223 ft3 annular vol. 120' X 0.2148 ft3/ft=25.78 ft3 shoe joint volume Total volume =223+25.78 =248.8 ft3=> 215 Sx @ 1.16 ft3/sk System: 215 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25%D800 retarder and 0.18%D167 fluid loss additive @ 15.8 PPG yieldin_ 1 . ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the 1 annik(K2) •rval to +/- 500' above the K2 interval with Class G +additives @ 15.8 ppg. - i ' o excess annular volume Lead: (5311' - 4285') X 0.1503 ft3/ft X 1.4 (40% excess)=216 ft3 annular vol. Total Volume=216 ft3=> 185 Sk @ 1.17 ft3/sk System: 185 Sx Class G + 0.2% D046 antifoamer, 0.3%D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 0 I 1\4 L ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-199 Plan: CD3-199 Plan: CD3-199wp07 a.k.a. 111 South or H Standard Proposal Report P1t, Pa 17 January, 2011 Changed Surface REVISED Casing depth. 2:31 pm, Jan 14, 2011 Updated geology and toolcodes. s HALLIBURTON • #"•'' Sperry Drilling Services ORIGINAL Northing (5000 ft/in) , IJ , , , 11 , 111 , 11 , 11 , , , I , , , , I , , , , 1 , , , , I , , , , I , , , , i , i1 , , , , I „ i , I , , , , I , , , , I 0 - N _ I r RI - 7 C RI1- 16 - O N M t7 M O — U - d O A Lo M O O M c? M 0 — M M U 0 0 - U U v - 0 Il r-- c) M o M CI o U o Ii o • o,- a - .\(:) 0 U U U U a / _ c . - cc:;&711! lir 0 N p Lo co c O t;, 1 M c Ic, N co M 0 MN w U o 11 U U� N J I O D �;, �� M Q 0 0M y U 0 a t , N0 ill" M .i. - . . U 3 U 1,1` ,_ �_ M rn Y U NM _❑ L M - UQ Olt i1 Z U — Cab Q 1, N U �Z C _O 0 Y rn d - t N- R C,a — p a Z LL - U • . 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O O -Lo N- o LOdM66 L-£a3 8 a) •_ , VLLG L !o 0 C 0co 7t• 00091, X miwil' N V , M to 00017 L _ -O O M "-c- 000£1, _ o °06 O Lf) O -In O 000Z I, o M O O - o O (� ,,o: `�p 000 L L _ -O o 0 N ppp U) • O 00001- _ _.) ° O O o t N. pOp 0006 , O N O O p co 00 x ppO 0 (SOS X O o -O o cb M r''' 1 o Mo V 0 0 co O O O O O O 0 0 0 0 0 in O Ln o Lo M 7r co N- (u!/14 (u!/11 0091.) 41daa Iea!Pan anal t . i0II r-, ._ ConocoPhillips H,ALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True '4. Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53°58'43.652 N From: Map Easting: -401.27ft Longitude: 152°19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-199 Well Position +NI-S 0.00 ft Northing: 6,003,878.77 ft ' Latitude: 70°25'10.386 N +E/-W 0.00 ft Easting: 388,383.47 ft . Longitude: 150°54'33.455 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft Wellbore Plan:CD3-199 11 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 1/14/2011 16.39 79.74 57,375 Design CD3-199wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +NI-S +EJ-W Direction (ft) (ft) (ft) (0) 28.00 0.00 0.00 143.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°HOOft) (°/100ft) (0) 28.00 0.00 0.00 28.00 -12.80 0.00 0.00 0.00 0.00 0.00 0.00 241.70 0.00 0.00 241.70 200.90 0.00 0.00 0.00 0.00 0.00 0.00 391.74 2.25 15.00 391.70 350.90 2.85 0.76 1.50 1.50 0.00 15.00 642.43 6.01 18.13 641.70 600.90 20.07 6.12 1.50 1.50 1.25 5.00 893.24 3.33 343.72 891.70 850.90 39.53 8.16 1.50 -1.07 -13.72 -150.00 1,193.24 4.48 301.64 1,191.06 1,150.26 54.04 -4.25 1.00 0.38 -14.03 -90.00 2,239.21 41.00 312.50 2,139.64 2,098.84 316.25 -302.20 3.50 3.49 1.04 11.96 5,488.22 41.00 312.50 4,591.70 4,550.90 1,756.30 -1,873.74 0.00 0.00 0.00 0.00 6,391.64 41.00 356.37 5,287.80 5,247.00 2,262.65 -2,115.96 3.14 0.00 4.86106.91 6,423.31 41.00 356.37 5,311.70 5,270.90 2,283.39 -2,117.28 0.00 0.00 0.00 0.00 8,869.86 83.00 135.00 6,960.80 6,920.00 2,194.79 -875.06 4.63 1.72 5.67 134.39 8,919.86 83.00 135.00 6,966.89 6,926.09 2,159.70 -839.97 0.00 0.00 0.00 0.00 9,135.48 89.60 135.00 6,980.80 6,940.00 2,007.64 -687.91 3.06 3.06 0.00 0.00 9,601.65 89.60 144.32 6,984.05 6,943.25 1,652.71 -386.50 2.00 0.00 2.00 90.01 15,773.65 89.60 144.32 7,026.80 6,986.00 -3,360.83 3,212.97 0.00 0.00 0.00 0.00 1/17/2011 9:57:42AMn R I PaLtge12‘( COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 ,', 0 # . ._w IPlanned Survey $ Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EJ-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -12.80 28.00 0.00 0.00 28.00 -12.80 0.00 0.00 6,003,878.77 388,383.47 0.00 0.00 100.00 0.00 0.00 100.00 59.20 0.00 0.00 6,003,878.77 388,383.47 0.00 0.00 200.00 0.00 0.00 200.00 159.20 0.00 0.00 6,003,878.77 388,383.47 0.00 0.00 241.70 0.00 0.00 241.70 200.90 0.00 0.00 6,003,878.77 388,383.47 0.00 0.00 Start Build 1.50 300.00 0.87 15.00 300.00 259.20 0.43 0.12 6,003,879.20 388,383.59 1.50 -0.27 391.74 2.25 15.00 391.70 350.90 2.85 0.76 6,003,881.61 388,384.27 1.50 -1.81 Start DLS 1.50 TFO 5.00 400.00 2.37 15.26 399.95 359.15 3.17 0.85 6,003,881.93 388,384.37 1.50 -2.02 500.00 3.87 17.10 499.80 459.00 8.39 2.39 6,003,887.13 388,385.98 1.50 -5.27 600.00 5.37 17.91 599.48 558.68 16.07 4.82 6,003,894.77 388,388.53 1.50 -9.94 642.43 6.01 18.13 641.70 600.90 20.07 6.12 6,003,898.75 388,389.89 1.50 -12.35 Start DLS 1.50 TFO-150.00 700.00 5.28 13.43 698.99 658.19 25.51 7.67 6,003,904.16 388,391.52 1.50 -15.75 800.00 4.13 1.50 798.65 757.85 33.58 8.83 6,003,912.21 388,392.80 1.50 -21.50 893.24 3.33 343.72 891.70 850.90 39.53 8.16 6,003,918.18 388,392.22 1.50 -26.66 Start DLS 1.00 TFO-90.00 900.00 3.33 342.55 898.45 857.65 39.91 8.05 6,003,918.55 388,392.11 1.00 -27.03 1,000.00 3.49 325.92 998.27 957.47 45.20 5.47 6,003,923.89 388,389.61 1.00 -32.81 1,100.00 3.92 311.84 1,098.06 1,057.26 50.01 1.22 6,003,928.75 388,385.43 1.00 -39.20 1,193.24 4.48 301.64 1,191.06 1,150.26 54.04 -4.25 6,003,932.87 388,380.02 1.00 -45.72 Start DLS 3.50 TFO 11.96 1,200.00 4.71 302.24 1,197.79 1,156.99 54.33 -4.71 6,003,933.16 388,379.57 3.50 -46.22 1,224.10 5.54 303.96 1,221.80 1,181.00 55.51 -6.52 6,003,934.37 388,377.78 3.50 -48.25 Base Permafrost 1,300.00 8.17 307.09 1,297.15 1,256.35 60.81 -13.86 6,003,939.77 388,370.52 3.50 -56.90 1,400.00 11.66 309.07 1,395.64 1,354.84 71.46 -27.37 6,003,950.63 388,357.17 3.50 -73.55 I 1,500.00 15.15 310.14 1,492.90 1,452.10 86.25 -45.21 6,003,965.69 388,339.56 3.50 -96.09 1,600.00 18.64 310.82 1,588.57 1,547.77 105.13 -67.30 6,003,984.89 388,317.75 3.50 -124.46 1,700.00 22.14 311.29 1,682.29 1,641.49 128.01 -93.56 6,004,008.16 388,291.84 3.50 -158.54 1,800.00 25.63 311.63 1,773.71 1,732.91 154.83 -123.90 6,004,035.42 388,261.91 3.50 -198.21 1,900.00 29.13 311.90 1,862.49 1,821.69 185.46 -158.19 6,004,066.57 388,228.08 3.50 -243.32 I 2,000.00 32.63 312.12 1,948.30 1,907.50 219.81 -196.32 6,004,101.48 388,190.48 3.50 -293.70 I 2,100.00 36.13 312.30 2,030.82 1,990.02 257.75 -238.14 6,004,140.03 388,149.23 3.50 -349.16 2,200.00 39.63 312.45 2,109.74 2,068.94 299.12 -283.49 6,004,182.07 388,104.51 3.50 -409.50 2,239.21 41.00 312.50 2,139.64 2,098.84 316.25 -302.20 6,004,199.48 388,086.06 3.50 -434.44 Start 3249.01 hold at 2239.21 MD 2,300.00 41.00 312.50 2,185.52 2,144.72 343.19 -331.60 6,004,226.86 388,057.06 0.00 -473.65 2,400.00 41.00 312.50 2,260.99 2,220.19 387.52 -379.97 6,004,271.89 388,009.37 0.00 -538.16 2,466.00 41.00 312.50 2,310.80 2,270.00 416.77 -411.90 6,004,301.62 387,977.88 0.00 -580.73 C-40 2,500.00 41.00 312.50 2,336.46 2,295.66 431.84 -428.34 6,004,316.93 387,961.67 0.00 -602.66 2,600.00 41.00 312.50 2,411.93 2,371.13 476.16 -476.71 6,004,361.97 387,913.97 0.00 -667.17 2,650.44 41.00 312.50 2,450.00 2,409.20 498.52 -501.11 6,004,384.69 387,889.91 0.00 -699.71 9-5/8"x 12-1/4" 1 1/17/2011 9:57.42AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 2,445.00 2,697.88 41.00 312.50 2,485.80 2,445.00 519.54 -524.06 6,004,406.05 387,867.28 0.00 -730.31 I C-30 2,700.00 41.00 312.50 2,487.40 2,446.60 520.48 -525.08 6,004,407.01 387,866.27 0.00 -731.68 2,800.00 41.00 312.50 2,562.87 2,522.07 564.81 -573.45 6,004,452.04 387,818.58 0.00 -796.19 2,900.00 41.00 312.50 2,638.34 2,597.54 609.13 -621.82 6,004,497.08 387,770.88 0.00 -860.69 3,000.00 41.00 312.50 2,713.81 2,673.01 653.45 -670.19 6,004,542.12 387,723.18 0.00 -925.20 3,100.00 41.00 312.50 2,789.28 2,748.48 697.78 -718.56 6,004,587.15 387,675.48 0.00 -989.71 3,200.00 41.00 312.50 2,864.75 2,823.95 742.10 -766.93 6,004,632.19 387,627.79 0.00 -1,054.22 3,205.36 41.00 312.50 2,868.80 2,828.00 744.47 -769.52 6,004,634.60 387,625.23 0.00 -1,057.67 C-20 3,300.00 41.00 312.50 2,940.23 2,899.43 786.42 -815.30 6,004,677.23 387,580.09 0.00 -1,118.72 3,400.00 41.00 312.50 3,015.70 2,974.90 830.74 -863.67 6,004,722.27 387,532.39 0.00 -1,183.23 3,500.00 41.00 312.50 3,091.17 3,050.37 875.07 -912.04 6,004,767.30 387,484.69 0.00 -1,247.74 3,600.00 41.00 312.50 3,166.64 3,125.84 919.39 -960.41 6,004,812.34 387,437.00 0.00 -1,312.25 3,700.00 41.00 312.50 3,242.11 3,201.31 963.71 -1,008.78 6,004,857.38 387,389.30 0.00 -1,376.75 3,800.00 41.00 312.50 3,317.58 3,276.78 1,008.03 -1,057.15 6,004,902.41 387,341.60 0.00 -1,441.26 3,900.00 41.00 312.50 3,393.05 3,352.25 1,052.36 -1,105.52 6,004,947.45 387,293.90 0.00 -1,505.77 4,000.00 41.00 312.50 3,468.52 3,427.72 1,096.68 -1,153.89 6,004,992.49 387,246.21 0.00 -1,570.27 4,100.00 41.00 312.50 3,543.99 3,503.19 1,141.00 -1,202.26 6,005,037.53 387,198.51 0.00 -1,634.78 4,200.00 41.00 312.50 3,619.46 3,578.66 1,185.32 -1,250.63 6,005,082.56 387,150.81 0.00 -1,699.29 4,300.00 41.00 312.50 3,694.94 3,654.14 1,229.65 -1,299.00 6,005,127.60 387,103.11 0.00 -1,763.80 4,400.00 41.00 312.50 3,770.41 3,729.61 1,273.97 -1,347.37 6,005,172.64 387,055.42 0.00 -1,828.30 4,500.00 41.00 312.50 3,845.88 3,805.08 1,318.29 -1,395.74 6,005,217.67 387,007.72 0.00 -1,892.81 I 4,550.25 41.00 312.50 3,883.80 3,843.00 1,340.56 -1,420.04 6,005,240.30 386,983.75 0.00 -1,925.22 K-3 4,600.00 41.00 312.50 3,921.35 3,880.55 1,362.62 -1,444.11 6,005,262.71 386,960.02 0.00 -1,957.32 4,700.00 41.00 312.50 3,996.82 3,956.02 1,406.94 -1,492.48 6,005,307.75 386,912.32 0.00 -2,021.83 4,745.02 41.00 312.50 4,030.80 3,990.00 1,426.89 -1,514.26 6,005,328.03 386,890.85 0.00 -2,050.87 K-3 Basal 4,784.78 41.00 312.50 4,060.80 4,020.00 1,444.51 -1,533.48 6,005,345.93 386,871.89 0.00 -2,076.51 K-2 4,800.00 41.00 312.50 4,072.29 4,031.49 1,451.26 -1,540.85 6,005,352.79 386,864.63 0.00 -2,086.33 4,900.00 41.00 312.50 4,147.76 4,106.96 1,495.58 -1,589.22 6,005,397.82 386,816.93 0.00 -2,150.84 4,921.25 41.00 312.50 4,163.80 4,123.00 1,505.00 -1,599.50 6,005,407.39 386,806.79 0.00 -2,164.55 K-2 Basal 5,000.00 41.00 312.50 4,223.23 4,182.43 1,539.91 -1,637.59 6,005,442.86 386,769.23 0.00 -2,215.35 5,100.00 41.00 312.50 4,298.70 4,257.90 1,584.23 -1,685.96 6,005,487.90 386,721.53 0.00 -2,279.86 5,200.00 41.00 312.50 4,374.17 4,333.37 1,628.55 -1,734.33 6,005,532.93 386,673.83 0.00 -2,344.36 5,300.00 41.00 312.50 4,449.65 4,408.85 1,672.87 -1,782.70 6,005,577.97 386,626.14 0.00 -2,408.87 5,400.00 41.00 312.50 4,525.12 4,484.32 1,717.20 -1,831.06 6,005,623.01 386,578.44 0.00 -2,473.38 5,488.22 41.00 312.50 4,591.70 4,550.90 1,756.30 -1,873.74 6,005,662.74 386,536.36 0.00 -2,530.29 Start DLS 3.14 TFO 106.91 5,500.00 40.89 313.04 4,600.59 4,559.79 1,761.54 -1,879.40 6,005,668.07 386,530.77 3.14 -2,537.88 I 5,600.00 40.10 317.72 4,676.66 4,635.86 1,807.72 -1,925.00 6,005,714.92 386,485.87 3.14 -2,602.20 5,700.00 39.49 322.54 4,753.51 4,712.71 1,856.80 -1,966.02 6,005,764.60 386,445.60 3.14 -2,666.08 1/17/2011 9.57.42AM Page 4 COMPASS 2003.16 Build 69 '-') ! I .I. L 's it ( � Ii "� I � ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 , Design: CD3-199wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,790.13 I 5,800.00 39.09 327.45 4,830.93 4,790.13 1,908.62 -2,002.33 6,005,816.96 386,410.07 3.14 -2,729.33 5,900.00 38.90 332.44 4,908.67 4,867.87 1,963.05 -2,033.83 6,005,871.84 386,379.39 3.14 -2,791.75 I 6,000.00 38.92 337.44 4,986.50 4,945.70 2,019.90 -2,060.41 6,005,929.08 386,353.66 3.14 -2,853.15 6,100.00 39.15 342.41 5,064.19 5,023.39 2,079.02 -2,082.01 6,005,988.51 386,332.95 3.14 -2,913.36 6,200.00 39.60 347.31 5,141.51 5,100.71 2,140.22 -2,098.55 6,006,049.95 386,317.33 3.14 -2,972.20 6,300.00 40.24 352.11 5,218.23 5,177.43 2,203.32 -2,109.99 6,006,113.20 386,306.84 3.14 -3,029.47 6,391.64 41.00 356.37 5,287.80 5,247.00 2,262.65 -2,115.96 6,006,172.61 386,301.76 3.14 -3,080.45 Start 31.67 hold at 6391.64 MD 6,400.00 41.00 356.37 5,294.11 5,253.31 2,268.13 -2,116.31 6,006,178.09 386,301.49 0.00 -3,085.03 6,423.31 41.00 356.37 5,311.70 5,270.90 2,283.39 -2,117.28 6,006,193.37 386,300.75 0.00 -3,097.80 Start DLS 4.63 TFO 134.39 6,500.00 38.58 0.44 5,370.63 5,329.83 2,332.42 -2,118.68 6,006,242.41 386,300.08 4.63 -3,137.81 6,600.00 35.67 6.42 5,450.38 5,409.58 2,392.61 -2,115.18 6,006,302.54 386,304.48 4.63 -3,183.77 6,700.00 33.10 13.25 5,532.93 5,492.13 2,448.19 -2,105.65 6,006,357.96 386,314.83 4.63 -3,222.43 I 6,744.94 32.07 16.62 5,570.80 5,530.00 2,471.57 -2,099.43 6,006,381.25 386,321.41 4.63 -3,237.35 Albian 97 6,800.00 30.95 21.00 5,617.74 5,576.94 2,498.80 -2,090.17 6,006,408.33 386,331.07 4.63 -3,253.53 6,900.00 29.32 29.65 5,704.27 5,663.47 2,544.11 -2,068.83 6,006,453.31 386,353.09 4.63 -3,276.87 7,000.00 28.30 39.04 5,791.93 5,751.13 2,583.82 -2,041.77 6,006,492.61 386,380.74 4.63 -3,292.30 7,100.00 27.96 48.85 5,880.17 5,839.37 2,617.68 -2,009.16 6,006,525.97 386,413.84 4.63 -3,299.72 7,168.68 28.13 55.62 5,940.80 5,900.00 2,637.42 -1,983.67 6,006,545.33 386,439.62 4.63 -3,300.14 Albian 96 1 7,200.00 28.32 58.66 5,968.40 5,927.60 2,645.45 -1,971.23 6,006,553.18 386,452.18 4.63 -3,299.07 7,300.00 29.35 68.03 6,056.04 6,015.24 2,666.97 -1,928.22 6,006,574.04 386,495.50 4.63 -3,290.37 7,400.00 31.00 76.66 6,142.53 6,101.73 2,682.08 -1,880.41 6,006,588.44 386,543.53 4.63 -3,273.67 7,500.00 33.16 84.39 6,227.30 6,186.50 2,690.70 -1,828.11 6,006,596.27 386,595.95 4.63 -3,249.07 7,600.00 35.74 91.20 6,309.79 6,268.99 2,692.76 -1,771.67 6,006,597.49 386,652.41 4.63 -3,216.75 7,700.00 38.66 97.16 6,389.46 6,348.66 2,688.25 -1,711.45 6,006,592.08 386,712.55 4.63 -3,176.91 7,800.00 41.84 102.38 6,465.80 6,425.00 2,677.20 -1,647.85 6,006,580.08 386,775.97 4.63 -3,129.81 7,900.00 45.23 106.97 6,538.30 6,497.50 2,659.68 -1,581.29 6,006,561.57 386,842.26 4.63 -3,075.76 7,960.05 47.35 109.46 6,579.80 6,539.00 2,646.10 -1,540.07 6,006,547.37 386,883.27 4.63 -3,040.10 Top HRZ 8,000.00 48.79 111.03 6,606.49 6,565.69 2,635.81 -1,512.19 6,006,536.67 386,910.99 4.63 -3,015.11 8,089.98 52.09 114.33 6,663.80 6,623.00 2,609.03 -1,448.23 6,006,508.94 386,974.53 4.63 -2,955.23 Base HRZ 8,100.00 52.47 114.67 6,669.93 6,629.13 2,605.74 -1,441.01 6,006,505.55 386,981.70 4.63 -2,948.26 8,179.68 55.48 117.32 6,716.80 6,676.00 2,577.48 -1,383.12 6,006,476.42 387,039.16 4.63 -2,890.85 K-1 8,200.00 56.25 117.97 6,728.20 6,687.40 2,569.67 -1,368.22 6,006,468.40 387,053.94 4.63 -2,875.65 8,243.43 57.92 119.31 6,751.80 6,711.00 2,552.20 -1,336.23 6,006,450.44 387,085.67 4.63 -2,842.44 Top Kuparuk D 8,300.00 60.12 120.98 6,780.92 6,740.12 2,527.84 -1,294.29 6,006,425.47 387,127.22 4.63 -2,797.75 8,309.86 60.50 121.26 6,785.80 6,745.00 2,523.41 -1,286.96 6,006,420.93 387,134.49 4.63 -2,789.80 Top Kuparuk C 1/17/2011 9:57.42AM n Page 5 1A ICOMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 Planned Survey Measured Vertical Map Map I Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section 1 (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,749.00 8,318.02 60.82 121.50 6,789.80 6,749.00 2,519.71 -1,280.89 6,006,417.14 387,140.51 4.63 -2,783.19 LCU 8,355.82 62.30 122.56 6,807.80 6,767.00 2,502.08 -1,252.71 6,006,399.09 387,168.41 4.63 -2,752.15 Top Nuiqsut 8,400.00 64.04 123.76 6,827.74 6,786.94 2,480.52 -1,219.71 6,006,377.04 387,201.09 4.63 -2,715.07 8,500.00 68.02 126.37 6,868.36 6,827.56 2,428.01 -1,144.96 6,006,323.42 387,275.04 4.63 -2,628.15 8,506.56 68.28 126.53 6,870.80 6,830.00 2,424.39 -1,140.06 6,006,319.73 387,279.88 4.63 -2,622.31 Base Nuiqsut 8,600.00 72.04 128.83 6,902.51 6,861.71 2,370.67 -1,070.53 6,006,264.98 387,348.59 4.63 -2,537.56 8,700.00 76.08 131.18 6,929.97 6,889.17 2,308.86 -996.91 6,006,202.08 387,421.28 4.63 -2,443.89 8,800.00 80.15 133.45 6,950.56 6,909.76 2,242.99 -924.58 6,006,135.14 387,492.61 4.63 -2,347.75 I 8,869.86 83.00 135.00 6,960.80 6,920.00 2,194.79 -875.06 6,006,086.21 387,541.40 4.63 -2,279.46 Start 50.00 hold at 8869.86 MD-Top Nechelik-7"x 8-3/4" 8,900.00 83.00 135.00 6,964.47 6,923.67 2,173.64 -853.91 6,006,064.75 387,562.23 0.00 -2,249.84 8,919.86 83.00 135.00 6,966.89 6,926.09 2,159.70 -839.97 6,006,050.60 387,575.96 0.00 -2,230.32 i Start DLS 3.06 TFO 0.00 ' 9,000.00 85.45 135.00 6,974.95 6,934.15 2,103.33 -783.60 6,005,993.40 387,631.47 3.06 -2,151.37 9,100.00 88.51 135.00 6,980.22 6,939.42 2,032.72 -712.99 6,005,921.75 387,701.01 3.06 -2,052.49 9,135.48 89.60 135.00 6,980.80 6,940.00 2,007.64 -687.91 6,005,896.30 387,725.71 3.06 -2,017.36 Start DLS 2.00 TFO 90.01 9,200.00 89.60 136.29 6,981.25 6,940.45 1,961.51 -642.80 6,005,849.50 387,770.12 2.00 -1,953.38 1 9,300.00 89.60 138.29 6,981.95 6,941.15 1,888.03 -574.98 6,005,775.03 387,836.83 2.00 -1,853.88 9,400.00 89.60 140.29 6,982.65 6,941.85 1,812.23 -509.76 6,005,698.27 387,900.90 2.00 -1,754.10 I 9,500.00 89.60 142.29 6,983.34 6,942.54 1,734.21 -447.23 6,005,619.32 387,962.26 2.00 -1,654.15 9,600.00 89.60 144.29 6,984.04 6,943.24 1,654.05 -387.46 6,005,538.29 388,020.82 2.00 -1,554.16 9,601.46 89.60 144.32 6,984.05 6,943.25 1,652.86 -386.61 6,005,537.09 388,021.65 2.00 -1,552.70 Start 6172.09 hold at 9601.46 MD 9,601.65 89.60 144.32 6,984.05 6,943.25 1,652.71 -386.50 6,005,536.94 388,021.76 2.00 -1,552.51 9,700.00 89.60 144.32 6,984.73 6,943.93 1,572.82 -329.14 6,005,456.20 388,077.91 0.00 -1,454.19 9,800.00 89.60 144.32 6,985.42 6,944.62 1,491.59 -270.82 6,005,374.11 388,135.00 0.00 -1,354.22 9,900.00 89.60 144.32 6,986.12 6,945.32 1,410.35 -212.50 6,005,292.03 388,192.10 0.00 -1,254.25 10,000.00 89.60 144.32 6,986.81 6,946.01 1,329.12 -154.18 6,005,209.94 388,249.19 0.00 -1,154.27 10,100.00 89.60 144.32 6,987.50 6,946.70 1,247.89 -95.86 6,005,127.85 388,306.28 0.00 -1,054.30 10,200.00 89.60 144.32 6,988.19 6,947.39 1,166.66 -37.54 6,005,045.77 388,363.38 0.00 -954.33 10,300.00 89.60 144.32 6,988.89 6,948.09 1,085.43 20.78 6,004,963.68 388,420.47 0.00 -854.36 10,400.00 89.60 144.32 6,989.58 6,948.78 1,004.20 79.10 6,004,881.60 388,477.56 0.00 -754.39 10,500.00 89.60 144.32 6,990.27 6,949.47 922.97 137.42 6,004,799.51 388,534.66 0.00 -654.42 10,600.00 89.60 144.32 6,990.96 6,950.16 841.74 195.73 6,004,717.42 388,591.75 0.00 -554.45 10,700.00 89.60 144.32 6,991.66 6,950.86 760.51 254.05 6,004,635.34 388,648.84 0.00 -454.48 10,800.00 89.60 144.32 6,992.35 6,951.55 679.28 312.37 6,004,553.25 388,705.94 0.00 -354.51 10,900.00 89.60 144.32 6,993.04 6,952.24 598.05 370.69 6,004,471.16 388,763.03 0.00 -254.54 11,000.00 89.60 144.32 6,993.73 6,952.93 516.82 429.01 6,004,389.08 388,820.12 0.00 -154.57 11,100.00 89.60 144.32 6,994.43 6,953.63 435.59 487.33 6,004,306.99 388,877.22 0.00 -54.59 11,200.00 89.60 144.32 6,995.12 6,954.32 354.36 545.65 6,004,224.91 388,934.31 0.00 45.38 11,300.00 89.60 144.32 6,995.81 6,955.01 273.13 603.97 6,004,142.82 388,991.40 0.00 145.35 1/17/2011 9:57.42AM 1 Page 6 ii. i COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 I Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,955.71 11,400.00 89.60 144.32 6,996.51 6,955.71 191.90 662.29 6,004,060.73 389,048.50 0.00 245.32 11,500.00 89.60 144.32 6,997.20 6,956.40 110.67 720.61 6,003,978.65 389,105.59 0.00 345.29 11,600.00 89.60 144.32 6,997.89 6,957.09 29.44 778.93 6,003,896.56 389,162.68 0.00 445.26 11,700.00 89.60 144.32 6,998.58 6,957.78 -51.79 837.25 6,003,814.47 389,219.78 0.00 545.23 11,800.00 89.60 144.32 6,999.28 6,958.48 -133.02 895.57 6,003,732.39 389,276.87 0.00 645.20 11,900.00 89.60 144.32 6,999.97 6,959.17 -214.25 953.89 6,003,650.30 389,333.96 0.00 745.17 12,000.00 89.60 144.32 7,000.66 6,959.86 -295.48 1,012.21 6,003,568.22 389,391.06 0.00 845.14 12,100.00 89.60 144.32 7,001.35 6,960.55 -376.71 1,070.53 6,003,486.13 389,448.15 0.00 945.11 12,200.00 89.60 144.32 7,002.05 6,961.25 -457.94 1,128.84 6,003,404.04 389,505.24 0.00 1,045.09 12,300.00 89.60 144.32 7,002.74 6,961.94 -539.17 1,187.16 6,003,321.96 389,562.34 0.00 1,145.06 12,400.00 89.60 144.32 7,003.43 6,962.63 -620.40 1,245.48 6,003,239.87 389,619.43 0.00 1,245.03 12,500.00 89.60 144.32 7,004.12 6,963.32 -701.63 1,303.80 6,003,157.78 389,676.52 0.00 1,345.00 12,600.00 89.60 144.32 7,004.82 6,964.02 -782.87 1,362.12 6,003,075.70 389,733.62 0.00 1,444.97 12,700.00 89.60 144.32 7,005.51 6,964.71 -864.10 1,420.44 6,002,993.61 389,790.71 0.00 1,544.94 12,800.00 89.60 144.32 7,006.20 6,965.40 -945.33 1,478.76 6,002,911.53 389,847.80 0.00 1,644.91 12,900.00 89.60 144.32 7,006.90 6,966.10 -1,026.56 1,537.08 6,002,829.44 389,904.90 0.00 1,744.88 13,000.00 89.60 144.32 7,007.59 6,966.79 -1,107.79 1,595.40 6,002,747.35 389,961.99 0.00 1,844.85 13,100.00 89.60 144.32 7,008.28 6,967.48 -1,189.02 1,653.72 6,002,665.27 390,019.08 0.00 1,944.82 13,200.00 89.60 144.32 7,008.97 6,968.17 -1,270.25 1,712.04 6,002,583.18 390,076.18 0.00 2,044.79 13,300.00 89.60 144.32 7,009.67 6,968.87 -1,351.48 1,770.36 6,002,501.09 390,133.27 0.00 2,144.77 13,400.00 89.60 144.32 7,010.36 6,969.56 -1,432.71 1,828.68 6,002,419.01 390,190.36 0.00 2,244.74 13,500.00 89.60 144.32 7,011.05 6,970.25 -1,513.94 1,887.00 6,002,336.92 390,247.46 0.00 2,344.71 13,600.00 89.60 144.32 7,011.74 6,970.94 -1,595.17 1,945.32 6,002,254.84 390,304.55 0.00 2,444.68 13,700.00 89.60 144.32 7,012.44 6,971.64 -1,676.40 2,003.63 6,002,172.75 390,361.64 0.00 2,544.65 13,800.00 89.60 144.32 7,013.13 6,972.33 -1,757.63 2,061.95 6,002,090.66 390,418.74 0.00 2,644.62 13,900.00 89.60 144.32 7,013.82 6,973.02 -1,838.86 2,120.27 6,002,008.58 390,475.83 0.00 2,744.59 14,000.00 89.60 144.32 7,014.51 6,973.71 -1,920.09 2,178.59 6,001,926.49 390,532.92 0.00 2,844.56 14,100.00 89.60 144.32 7,015.21 6,974.41 -2,001.32 2,236.91 6,001,844.40 390,590.02 0.00 2,944.53 14,200.00 89.60 144.32 7,015.90 6,975.10 -2,082.55 2,295.23 6,001,762.32 390,647.11 0.00 3,044.50 14,300.00 89.60 144.32 7,016.59 6,975.79 -2,163.78 2,353.55 6,001,680.23 390,704.20 0.00 3,144.47 14,400.00 89.60 144.32 7,017.29 6,976.49 -2,245.01 2,411.87 6,001,598.15 390,761.30 0.00 3,244.45 14,500.00 89.60 144.32 7,017.98 6,977.18 -2,326.24 2,470.19 6,001,516.06 390,818.39 0.00 3,344.42 14,600.00 89.60 144.32 7,018.67 6,977.87 -2,407.47 2,528.51 6,001,433.97 390,875.48 0.00 3,444.39 14,700.00 89.60 144.32 7,019.36 6,978.56 -2,488.70 2,586.83 6,001,351.89 390,932.58 0.00 3,544.36 14,800.00 89.60 144.32 7,020.06 6,979.26 -2,569.93 2,645.15 6,001,269.80 390,989.67 0.00 3,644.33 14,900.00 89.60 144.32 7,020.75 6,979.95 -2,651.16 2,703.47 6,001,187.71 391,046.76 0.00 3,744.30 15,000.00 89.60 144.32 7,021.44 6,980.64 -2,732.39 2,761.79 6,001,105.63 391,103.86 0.00 3,844.27 15,100.00 89.60 144.32 7,022.13 6,981.33 -2,813.62 2,820.11 6,001,023.54 391,160.95 0.00 3,944.24 15,200.00 89.60 144.32 7,022.83 6,982.03 -2,894.85 2,878.43 6,000,941.46 391,218.04 0.00 4,044.21 15,300.00 89.60 144.32 7,023.52 6,982.72 -2,976.08 2,936.74 6,000,859.37 391,275.14 0.00 4,144.18 15,400.00 89.60 144.32 7,024.21 6,983.41 -3,057.32 2,995.06 6,000,777.28 391,332.23 0.00 4,244.16 15,500.00 89.60 144.32 7,024.90 6,984.10 -3,138.55 3,053.38 6,000,695.20 391,389.32 0.00 4,344.13 1 15,600.00 89.60 144.32 7,025.60 6,984.80 -3,219.78 3,111.70 6,000,613.11 391,446.42 0.00 4,444.10 15,700.00 89.60 144.32 7,026.29 6,985.49 -3,301.01 3,170.02 6,000,531.02 391,503.51 0.00 4,544.07 1/17/2011 9:57:42AM 1 •,') t Page 7 a ;T, COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 Planned Survey Measured Vertical Map Map ' Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,986.00 1 15,773.55 89.60 144.32 7,026.80 6,986.00 -3,360.75 3,212.92 6,000,470.65 391,545.50 0.00 4,617.60 TD at 15773.55-3-1/2"x 6-1/8" [ 15,773.65 89.60 144.32 7,026.80 6,986.00 -3,360.83 3,212.97 6,000,470.57 391,545.56 0.00 4,617.70 CD3-H 25May10 Toe Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-H 25May10 Toe 0.00 0.00 7,026.80 -3,360.83 3,212.97 6,000,470.57 391,545.56 -plan hits target center -Circle(radius 100.00) CD3-H wp07 Heel 0.00 0.00 6,960.80 2,194.40 -875.30 6,006,085.83 387,541.15 -plan hits target center -Circle(radius 100.00) i Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C') 2,650.44 2,450.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 8,869.86 6,960.80 7"x 8-3/4" 7 8-3/4 15,773.55 7,026.80 3-1/2"x 6-1/8" 3-1/2 6-1/8 J 1/17/2011 9:57:42AM 1j R i G i f e8 A L COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTD J Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-199 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.8 @ 40.80ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-199 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-199 Design: CD3-199wp07 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 8,869.86 6,960.80 Top Nechelik 4,745.02 4,030.80 K-3 Basal 2,466.00 2,310.80 C-40 4,784.78 4,060.80 K-2 8,089.98 6,663.80 Base HRZ 8,355.82 6,807.80 Top Nuiqsut 7,168.68 5,940.80 Albian 96 8,309.86 6,785.80 Top Kuparuk C 7,960.05 6,579.80 Top HRZ 8,506.56 6,870.80 Base Nuiqsut 8,318.02 6,789.80 LCU 3,205.36 2,868.80 C-20 2,697.88 2,485.80 C-30 6,744.94 5,570.80 Albian 97 1,224.10 1,221.80 Base Permafrost 4,550.25 3,883.80 K-3 • 8,243.43 6,751.80 Top Kuparuk D 8,179.68 6,716.80 K-1 4,921.25 4,163.80 K-2 Basal Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (ft) (ft) (ft) (ft) Comment 241.70 241.70 0.00 0.00 Start Build 1.50 391.74 391.70 2.85 0.76 Start DLS 1.50 TFO 5.00 642.43 641.70 20.07 6.12 Start DLS 1.50 TFO-150.00 893.24 891.70 39.53 8.16 Start DLS 1.00 TFO-90.00 1,193.24 1,191.06 54.04 -4.25 Start DLS 3.50 TFO 11.96 2,239.21 2,139.64 316.25 -302.20 Start 3249.01 hold at 2239.21 MD 5,488.22 4,591.70 1,756.30 -1,873.74 Start DLS 3.14 TFO 106.91 6,391.64 5,287.80 2,262.65 -2,115.96 Start 31.67 hold at 6391.64 MD 6,423.31 5,311.70 2,283.39 -2,117.28 Start DLS 4.63 TFO 134.39 8,869.86 6,960.80 2,194.79 -875.06 Start 50.00 hold at 8869.86 MD 8,919.86 6,966.89 2,159.70 -839.97 Start DLS 3.06 TFO 0.00 9,135.48 6,980.80 2,007.64 -687.91 Start DLS 2.00 TFO 90.01 9,601.46 6,984.05 1,652.86 -386.61 Start 6172.09 hold at 9601.46 MD 15,773.55 7,026.80 -3,360.75 3,212.92 TD at 15773.55 1/17/2011 9:57:42AM Page 9 COMPASS 2003.16 Build 69 ORIGINAL_ Z N ©L 0 I'mL m ixw 3 m C J ° J L a fit Q CO1 in2 m Z E ID N C O N U • O• N •MI fl 0• N cu w • 3 • m U C mow L i a coo �r w• M o m W o `V • U ro m . , Z N „:, O O ea 0 m E E RS U c . c allit CO rt..," e Z a Q N 3 ICC C � oO Q • „ W - _a 13 U V v p m Q L O C tO N N , O = ^ a Kf O O v W _ L C C J • O O N• R Z $'. 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D\ V‘ .'' � a�14 •�. p Oltf 'VI ipkigitla-t: "2.1,2!:;#5,,,. :1Pf- . 5 II cm in co lit 9§., iii ����►//��►�I�IG�� Cr) d R:66 C —dF 11E1 gg T ,\ N a§@@ 888 o m M 0, GC 4848 HIP - � o Igiii A NIORIGINAL _0- Ili! HALLIBURTON ConocoPhillips CD3-199wp07 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 14:46,January 14 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 15773.55 Results Limited By: Centre Distance: 1774.56 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1125.00 CD3-199wp07(Plan: CD3-199) CB-GYRO-SS 1125.00 2650.44 CD3-199wp07(Plan:CD3-199) MWD+IFR-AK-CAZ-SC 2650.44 8869.86 CD3-199wp07(Plan: CD3-199) MWD+IFR-AK-CAZ-SC 8869.86 15773.55 CD3-199wp07(Plan: CD3-199) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2650.44 9-5/8"x 12-1/4" 9-5/8 6960.80 8869.86 7"x 8-3/4" 7 7026.80 15773.55 3-1/2"x 6-1/8" 3-1/2 o11. V t7 (y U - •9I,iIlIIII�I �I _ I ` g 60 41411117 I i v C0 iI CO 'I1 d _ !j 41111 30 lir 1111111111 11 112 1Il�, 11111YI �- N‘c ""jl Il 0 I I I I I I I I I I I I I I I I I f 1 0 1500 3000 4500 6000 7500 9000 Measured Depth LEGEND CD3-106,CD3-108,CD3-106 VO -X- CD3-112,CD3-112,CD3-112 V3 CD3-302,CD3-302PB2,CD3-302PB2 V6 - CD3-106,CD3-106L1, CD3-106L1 VO --1- CD3-113,CD3-113,CD3-113 V6 -A- CD3302,CD3-302PB3,CD3-302PB3 V2 - CD3-107,CD3-107,CD3-107 V7 CD3-121,CD3-121,CO3-121 VO -X- CD3-303,CD3-303,CD3-303 VO - CD3-107,CD3-107L1,CD3-107L1 VO -X- CD3301,CD3-301,CD3-301 V4 CD3-304,CD3-304,CD3-304 VO - CD3-107,CD3-307,CD3-307 V4 -A- CD3-301,CD3-301A,C03301A VO -e- CD3305,CD3-305,CD3-305 VO CD3-108,CD3-108,CD3-108 V14 CD3301,CD3-301APB1,CD3-301APB1 VO-0- CD3-305,CD3-305PB1,CD3-305PB1 VO $- CD3-109,CO3-109,CD3-109 V5 -e- CD3301,CD3-301PB1,CD3-301PB1 V1 -- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO - CD3-110,CD3-110,CD3-110 V12 - CD3-302,CD3-302,CD3-302 V3 -- Plan:CD3-120,Plan:CD3-120,CD3-120wp06 VO - CD3-111,CD3-111,CD3-111 V7 -9- CD3-302,CD3-302A,CD3-302A VO -9- Plan:CD3-198,Plan:CD3-198,CD3-198wp07 VO CD3-111,CD3-111L1,CD3-111L1 V1 -e- CD3-302,CD3-302PB1,CD3-302PB1 V11 -8- CD3-199wp07 HALLIBURTON ConocoPhillips CD3-1 99wp07 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 14:46,January 14 2011 Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 15773.55 Results Limited By: Centre Distance: 1774.56 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1125.00 CD3-199wp07(Plan: CD3-199) CB-GYRO-SS 1125.00 2650.44 CD3-199wp07(Plan:CD3-199) MWD+IFR-AK-CAZ-SC 2650.44 8869.86 CD3-199wp07(Plan: CD3-199) MWD+IFR-AK-CAZ-SC 8869.86 15773.55 CD3-199wp07(Plan: CD3-199) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2650.44 9-5/8"x 12-1/4" 9-5/8 6960.80 8869.86 7"x 8-3/4" 7 7026.80 15773.55 3-1/2"x 6-1/8" 3-1/2 1 ® m 2 i F 6"6" e v w , u u u = J � j/ \ ,ji 111.1 i 76', cn III vsrl\,.„." 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N t Z i0) r •l 1� U _ �u'��i. i�il I III,.� �I1I'I , ......, , , 0 I I I I I I I I I I I I I , I I , I I I I I I I I I I I , , I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND - CD3-106,CD3-106,CD3-106 VO -X- CD3-112,CD3-112,CD3-112 V3 -4- CD3-302,CD3-302PB2,CD3-302PB2 V6 $- CD3-106,CD3-106L1,CD3-106L1 VO -#- CD3-113,CD3-113,CD3-113 V6 -A- CD3-302,CD3-302PB3,CD3-302PB3 V2 -4- CO3-107,CD3-107,CD3-107 V7 -4- CD3-121,CD3-121,CD3-121 VO -X- CD3-303,CD3-303,CD3-303 VO -fa- CO3.107,CD3-107L1,CD3-107L1 VO -X- CD3-301,CD3301,CD3-301 V4 --1-- CD3-304,CD3304,CD3-304 VO - CD3-107,CO3-307,CD3-307 V4 -A- CD3-301,CD3-301A,CD3301A VO _e- CD3-305,CD3-305,CD3305 VO CD3-108,CD3-108,CD3-108 V14 -0- CD3-301,CD3301APB1,CD3-301APB1 V0-4- CD3-305,CD3-305PB1,CD3-305PB1 VO CD3-109,CD3-109,CD3-109 V5 -e- CD3-301,CD3301PB1,CD3-301PB1 V1 -e- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO -X- CD3-110,CD3-110,CD3-110 V12 -I-- CD3-302,CD3-302,CD3-302 V3 --A- Plan:CD3-120,Plan:CD3-120,CD3-120wp06 V0 $- CD3-111,CD3-111,CD3-111 V7 -B- CD3-302,CD3-302A,CD3302A VO _9- Plan:CD3-198,Plan:CD3-198,CD3-198wp07 VO - CD3-111,CD3-111L1,CD3-111L1 V1 -e- CD3302,CD3302PB1,CD3-302PB1 V11 _8- CD3-199wp07 Y:,, j1 . 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SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-XqA, 1.57f4-54 35 70' 25' 09 267" 15n• 54' 44. 77A" 1392' 642' 7 ; 17 5 CD3-X99 6,003 625.99 1 528,415.38 70' 25' 09.21" 150' 54' 44.833" 1387' 661' 7.3 12.8 , CUS-301 6,Ob3 �T33� 17528,395.58 70' 25' 09.1 2'' 150' 54' 45.411" 1387 680' 7.3 13.5 CD3-302 6,003,616.72 1,528,376.38 70' 25' 09.124" 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6,003,612.52 1,528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3-304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150' 54' 47.122" 1368' 739' 7.3 13.4 CD3-305 6,003.603.48 1,528.317.56 70' 25' 08.985" 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6,003,599.43 1,528,298.37 70' 25' 08.942" 150' 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150' 54' 48.820" 1354' 797' 7.3 13.2 CD3-108 6.003,589.85 1,528.259.61 70' 25' 08.842" 150' 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962" 1344' 836' 7.3 13.1 CD3-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54' 50.533" 1339' 855' 7.3 13.0 CD3-111 6,003.576.13 1,528,201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54' 51.676" 1330' 894' 7.3 13.1 CD3-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54' 52.255" 1325' 914' 7.3 13.1 CD3-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150' 54' 52.815" 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54' 53.388" 1315' 953' 7.3 13.2 CD3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150' 54' 53.950" 1311' 972' 7.3 13.2 003-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 13.1 CD3-118 6,003,544.88 1,528,064.44 70' 25' 08.372" 150' 54' 55.086" 1301' 1011' 7.3 12.8 CD3-X19 6.003.540.17 1,528.044.86 70' 25' 08.322" 150' 54' 55.660" 1296' 1030' 7.3 12.8 CD3-X20 6.003.535.95 1,528,025.39 70' 25' 08.278" 150' 54' 56.229" 1291' 1050' 7.3 12.6 CD3-X21 6.003.531.41 1,528,006.04 70' 25' 08.230" 150' 54' 56.794" 1286' 1069' 7.3 12.5 003-122 6,003,527.00 1,527,986.67 70' 25' 08.184" 150' 54' 57.360" 1282' 1088' 7.3 12.6 CD3-X23 6.003,522.43 1.527.967.12 70' 25' 08.136" 150' 54' 57.932" 1277' 1108' 7.3 12.6 CD3-124 6,003,518.17 1,527.947.59 70' 25' 08.091" 150' 54' 58.502" 1272' 1127' 7.3 12.5 CD3-X25 6.003,513.62 1,527.927.89 70' 25' 08.044" 150' 54' 59.078" 1267' 1147' 7.3 12.6 CD3-X26 6.003.508.97 1,527.908.70 70' 25' 07.995" 150' 54' 59.639" 1263' 1166' 7.3 12.6 CD3-X27 6.003,503.45 1,527,889.34 70' 25' 07.948" 150' 55' 00.204" 1258' 1185' 7.3 12.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) IIPV" ALPINE MODULE:CD30 UNIT: CD Conoc.Phillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 CE-`CD30-111 2 OF 3 9 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLISTOc, WELL NAME 006' Cb PTD# 2--/ / C-I C Development Service Exploratory Stratigraphic Test Non-Conventional Well 6', FIELD: l �'7 /(� L POOL: Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL 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 perforate and 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 target 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. Rev: 1/11/2008 m o rr- a (o -n 'a 3 D 111 o 0 -, o Cn 'a ; 0 3• r- 0 G) C m vi _ r 3 ° , -. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 14 15:45: 19 2011 Reel Header Service name LISTPE Date 11/03/14 Origin STS Reel Name UNKNOWN Continuation Number Ol Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/03/14 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD3-199 API NUMBER: 501032063500 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 14-MAR-11 JOB DATA MWD RUN 3 MWD RUN 6 JOB NUMBER: K-MW-000789602 K-MW-000789602 LOGGING ENGINEER: TYLER RITCHE JACK KLEINHA OPERATOR WITNESS: GRANVILLE RI FRED HERBERT SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 3893 FSL: FEL: 661 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 40.40 GROUND LEVEL: 12.80 gll-oi b c90669 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9. 625 2662.0 2ND STRING 6.125 7.000 8870.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 100, 400 AND 500 WERE CLEAN OUT RUNS NO DATA PRESENTED. 4 . MWD RUN 200 WAS DIRECTIONAL ONLY - NO DATA PRESENTED. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 6. MWD RUN 600 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AT BIT INCLINATION (ABI) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) AND GEOPILOT ROTARY STEERABLE SYSTEM (RSS) . 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 8. MWD RUNS 100 - 600 REPRESENTS WELL CD3-199 WITH API 50-103-20635-00-00. THIS WELL REACHED A TOTAL DEPTH OF 15, 742' MD, 7, 008 ' TVD. MNEMONIC CURVE DESCRIPTION R09P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED 6. 125" MUD WEIGHT: 9. 65 - 10.35 PPG WHOLE MUD CHLORIDES: 55, 000 - 94, 000 PPM CL FORMATION WATER SALINITY: 23, 000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ROTATING: ALL DATA AQUIRED WHILE ROTATING ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR GAMMA RAY AND ROP. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. $ File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2613.5 15693.0 RPS 2652.0 15700.5 FET 2652.0 15700.5 RPD 2652.0 15700.5 RPX 2652.0 15700.5 RPM 2652.0 15700.5 ROP 2673.5 15742.0 NPHI 8808.0 15656.0 DRHO 8808.0 15671.0 NCNT 8808.0 15656.0 CALN 8808.0 15671.0 FCNT 8808.0 15656.0 PEF 8808.0 15671.0 RHOB 8808 .0 15671.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 2613.5 8879.0 MWD 6 8808.0 15742.0 $ 1 # REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 GR MWD API 4 1 68 20 6 FET MWD HR 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPM MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 FCNT MWD CP30 4 1 68 48 13 NCNT MWD CP30 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2613.5 15742 9177.75 26258 2613.5 15742 RHOB MWD G/CC 0.88 3.255 2.4701 13727 8808 15671 DRHO MWD G/CC -1. 952 0.361 0.060052 13727 8808 15671 CALN MWD IN 5. 63 9.48 6. 15656 13727 8808 15671 PEF MWD B/E 1.38 15.26 2.222 13727 8808 15671 GR MWD API 23.29 408. 61 85. 9709 26160 2613. 5 15693 FET MWD HR 0.23 223.89 1.55327 26036 2652 15700.5 RPX MWD OHMM 0.1 1814 .83 7. 61242 26036 2652 15700.5 RPS MWD OHMM 0.1 2000 8.36788 26036 2652 15700.5 RPM MWD OHMM 0.11 1703.84 9.49558 26036 2652 15700.5 RPD MWD OHMM 0.15 2000 10.5493 26036 2652 15700.5 ROP MWD FPH 0 272.18 103.524 26138 2673.5 15742 FCNT MWD CP30 223.57 1421.78 833.362 13697 8808 15656 NCNT MWD CP30 16537. 6 38072. 9 30706.3 13697 8808 15656 NPHI MWD PU 12. 68 27. 9 18.5883 13697 8808 15656 First Reading For Entire File 2613.5 Last Reading For Entire File 15742 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2613.5 8819.0 R15P 2652.0 8828.5 R39P 2652.0 8828.5 R27P 2652.0 8828.5 R09P 2652.0 8828.5 EWXT 2652.0 8828.5 ROPA 2673.5 8879.0 $ LOG HEADER DATA DATE LOGGED: 19-FEB-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 8879.0 TOP LOG INTERVAL (FT) : 2673.0 BOTTOM LOG INTERVAL (FT) : 8879.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 26.4 MAXIMUM ANGLE: 82. 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 10505932 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2662.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.70 MUD VISCOSITY (S) : 39.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .777 141. 4 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: 1. 900 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 f Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2613.5 8879 5746.25 12532 2613.5 8879 GR MWD030 API 47.44 408. 61 123.008 12412 2613.5 8819 FET MWD030 HR 0.23 80. 65 1.54241 12354 2652 8828.5 RPX MWD030 OHMM 0.36 649. 6 4.75277 12354 2652 8828 .5 RPS MWD030 OHMM 0.24 2000 5.02486 12354 2652 8828.5 RPM MWD030 OHMM 0. 11 1519.38 4 . 99208 12354 2652 8828.5 RPD MWD030 OHMM 0. 15 2000 7.75504 12354 2652 8828.5 ROP MWD030 FPH 0 272. 18 117. 909 12412 2673.5 8879 First Reading For Entire File 2613.5 Last Reading For Entire File 8879 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH APEL 8808.0 15671.0 TNPS 8808.0 15656.0 AHSI 8808.0 15671.0 TNFA 8808.0 15656.0 ADCL 8808.0 15671.0 TNNA 8808.0 15656.0 ACDL 8808.0 15671.0 DGRC 8819.5 15693.0 R15P 8860.0 15700.5 EWXT 8860.0 15700.5 R27P 8860.0 15700.5 R39P 8860.0 15700.5 R09P 8860.0 15700.5 ROPA 8879.5 15742. 0 $ LOG HEADER DATA DATE LOGGED: 06-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15742. 0 TOP LOG INTERVAL (FT) : 8879.0 BOTTOM LOG INTERVAL (FT) : 15742.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 83.3 MAXIMUM ANGLE: 91. 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 91360 CTN COMP THERMAL NEUTRON 11301941 EWR4 Electromag Resis. 4 11261763 ALD Azimuthal Litho-Dens 249341 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 DRILLER'S CASING DEPTH (FT) : 8870.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.30 MUD VISCOSITY (S) : 46.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 94213 FLUID LOSS (C3) : 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .080 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .034 176.7 MUD FILTRATE AT MT: .080 70. 0 MUD CAKE AT MT: . 100 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD060 G/CC 4 1 68 4 2 DRHO MWD060 G/CC 4 1 68 8 3 CALN MWD060 IN 4 1 68 12 4 PEF MWD060 B/E 4 1 68 16 5 GR MWD060 API 4 1 68 20 6 FET MWD060 HR 4 1 68 24 7 RPX MWD060 OHMM 4 1 68 28 8 RPS MWD060 OHMM 4 1 68 32 9 RPM MWD060 OHMM 4 1 68 36 10 RPD MWD060 OHMM 4 1 68 40 11 ROP MWD060 FPH 4 1 68 44 12 FCNT MWD060 CP30 4 1 68 48 13 NCNT MWD060 CP30 4 1 68 52 14 NPHI MWD060 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8808 15742 12275 13869 8808 15742 RHOB MWD060 G/CC 0.88 3.255 2. 4701 13727 8808 15671 DRHO MWD060 G/CC -1.952 0.361 0.060052 13727 8808 15671 CALN MWD060 IN 5. 63 9.48 6. 15656 13727 8808 15671 PEF MWD060 B/E 1.38 15.26 2.222 13727 8808 15671 GR MWD060 API 23.29 90.79 52.5329 13748 8819.5 15693 FET MWD060 HR 0.26 223.89 1.56308 13682 8860 15700.5 RPX MWD060 OHMM 0.1 1814 .83 10. 1945 13682 8860 15700.5 RPS MWD060 OHMM 0.1 1681.26 11.3864 13682 8860 15700.5 RPM MWD060 OHMM 2.3 1703.84 13.562 13682 8860 15700.5 RPD MWD060 OHMM 3. 11 2000 13.0722 13682 8860 15700.5 ROP MWD060 FPH 5.75 260.55 90.5149 13726 8879.5 15742 FCNT MWD060 CP30 223.57 1421.78 833.362 13697 8808 15656 NCNT MWD060 CP30 16537. 6 38072. 9 30706.3 13697 8808 15656 NPHI MWD060 PU 12. 68 27. 9 18.5883 13697 8808 15656 First Reading For Entire File 8808 Last Reading For Entire File 15742 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/03/14 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 11/03/14 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/03/14 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF a+ e Physical EOF End Of LIS File
