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212-007
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 19,375 feet None feet true vertical 6,772 feet None feet Effective Depth measured 19,375 feet 14,993 feet true vertical 6,772 feet 6,717 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3.5" L-80 15046' MD 6,724' TVD Packers and SSSV (type, measured and true vertical depth)14,993'MD 2,399' MD 6,717' TVD 1,997' 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:Fiord-Nechelik 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: 6,770'-6,770': 2024 Perfs: 6,775'-6,775', 6,760'-6,760' and 6,762'-6,762' TVD 3650 2484 4.5" Burst Collapse Liner 15208' 4365' Casing 6753 6772 15242 19358 3613.9' 116Conductor Surface measured TVD 7.625" Plugs Junk measured Length measured true vertical Packer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-007 50-103-20653-00-00 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, 372105, 364470, 364471, 364472 Alpine Pool CRU CD3-119 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 356 Gas-Mcf MD 1098 Size 116 739 13082105 161 207450 227 Intermediate 16" 10.75" 80' N/A Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 2546 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 (locked out) Mark Shulman mark.shulman@cop.com (907) 263-3782Sr. Production Engineer Perf Pups from 15,810'-19,316' MD: 2024 Perfs: 15,600'-15,620' MD, 17,000'-17,020' MD and 19,000'-19,020' MD Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 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 7:32 am, Apr 23, 2024 Mark Shulman Digitally signed by Mark Shulman Date: 2024.04.22 16:47:36 -08'00' Adobe Acrobat Reader version: 2024.001.20643 DSR-4/23/24 RBDMS JSB 04302024 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 ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS By Kayla Junks at4:31 pm, Apr 04,2023 1. Operations Susp Well Insp ❑ Plug Perforations Fracture Stimulate C Pull Tubing U Operations shutdown 0 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 ❑ 212-007 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20653-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372104, 372105, 364470, 364471, 364472 CRU CD3-119 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field/Alpine 11. Present Well Condition Summary: Total Depth measured 19,375 feet Plugs measured None feet true vertical 6,772 feet Junk measured None feet Effective Depth measured 19,375 feet Packer measured 14,993 feet true vertical 6,772 feet true vertical 6,717 feet Casing Length Size MD TVD Burst Collapse Conductor 80, 16" 116 116 Surface 3613.9' 10.75" 3650 2484 Intermediate 15208' 7.625" 15242 6753 Liner 4365' 4.5" 19358 6772 Perforation depth Measured depth Pert Pups from 15,810'-19,316' MD: 2023 Parts: 16,080'-16,100' MD, 16,380'-16,400' MD and 17,400'-17,420' MD True Vertical depth 6,770'-6,770': 2023 Perfs: 6,761'-6,761', 6,759'-6,759' and 6,743'-6,748' TVD Tubing (size, grade, measured and true vertical depth) 3.5" L-80 15046' MD 6,724' TVD Packers and SSSV (type, measured and true vertical depth) Packe[HRD ZXP Liner Top Packer 14,993'MD 6,717' TVD SSSV-Cameo TRMAXX-5E 2,399' MD 1,997' 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: 146 2452 478 1137 231 Subsequent to operation: 549 3968 1264 930 280 13b. Pools active after work: 14. Attachments (required per 20 AAC 25.070. 25.071, 8 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 N/A if C.O. Exempt: Digitally signed by Mark Shulman N/A Authorized Name and Mar S U m a n Date: 2023.04.0416:00.43 -08'00' Digital Signature with Date: Contact Name: Mark Shulman Contact Email: mark.shulma2(O7.C2D.c0m Authorized Title: Sr. Production Engineer Contact Phone: (907) 263-3782 Sr Pet Eng: ISr Pet Geo: I ISr Res Eng: DSR-4/4/23 RBDMS JSB 040623 Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov CD3-119 Perforations DTTMSTART JOBTYP SUMMARYOPS 3/14/2023 MAINTAIN WELL RIH W / GUN RUN #2. PERFORATE FROM 16380'-16400'. RIH WITH GUN RUN #3. PERFORATE FROM 16080' TO 16100'. 3/13/2023 MAINTAIN WELL RIH WITH MOTOR AND 2.64" JUNK MILL. DRY TAG AT 18,200' (500' PAST TARGET DEPTH). RIH W / GUN RUN #1 PERFORATE FROM 17400' TO 17420' WINS PROD WELLNANIE CD3-119 WELLBORE CD3-119 QnocOi AM Alaska, Inc. ww - R PORT COLLAR SAFETY FLOAT STAGE CO WS GAG PACKERII NIPPLE HANGER:, SEAL SBE 1. .1 Factor Saul Psi PERFP', APERF', APERF, PERFP, APERF', PERFP, APERF'. PERFP PERFP', PERFP, APERP, APERF', PER FP, PERFP, Swel Pea.,', PERFP', PERFP PERFP PERFP', SHOE; LINER; Well Attributes I Max Angle&MD ITO FIeM Name WNNone, APWWI Wellhore Statue Id(°) MB(IIKBI Aci.,m(IIKB) FIORD NE HELIK 1 2 PR D 268 1],622A6 19,3J5.0 Grimmer, X351ppm) Date Anm,Nian Entl ONe KB-NIup RR Date OIM1er Elrv... LETOLast WO: 4I232012 Annotation Depth gtKIH 1 WellbornI Endo. Larthloi Last Tag: COZ119 Tar Last Rev Reason Annotation WeIINrt 1 End Data 1 Lail Mad By Rev Reason: Pull Gauges COZ119 4"LI2022 bePM1mbh Casing Strings Set Depth aM Doing Ci9 Dea ( inI NO (in) Top upi (pi INDHKKB) WILL-llbmlRH40� e Top Thread CONDUCTOR 16 15.06 36.0 116.0 116.0 62.50 WELDED 10314 9.95 36.5 3,650.4 2,4837 45.50 BTCM INTERMEDIATE 1bo; b.8] 34.3 15,242.J 6, 153.4 29.]0 BTCM LINER 4112 3.96 14,992.7 IU,35d.01 6,7717 12.fi0 L-80 IBTRR Tubing Strings: string max indicates LONGEST segment of string Top (ARE) . Depth... art Depth,,, string Ma... Tubing Description Wtgbm) Grade Topcon-on Ii 31.3 15,046.1 6,724.5 312 TUBING 9.30 L-80 EUE8RD 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Our Top RVO) Top lncl Nomnal Nominal Inputs.) IXK9) E) hem Des (in) Core Meke Model ID gn) 31.3 31.3 0.00 HANGER 8.000 FMC TUBING HANGER FMC PN: 4.500 118318- 0001, ASN: 4J9- 8650 145.4 145.4 0.91 XO Reducing 4.500 CROSSOVER 4.5 x 3.5,#1L-80, GEM PIN 3.500 EUEBRD 1OM194 ] 2,399.3 1,997.4 64.04 SAFETYVLV 5.180 CANDO TRMAQ(-5E rat 2.812'X Scblum- PN: 2.812 PROFILE TO 114"CONTROL LINE Camco 1004692 29, ser# C11S- 0034 5,910.3 3,391.2 66.75 GAS LIFT 5.390 312" Camco KBMG GLM 9.3# L40 CAMCO KBMG 2.920 EUE 8m 11,514.9 5,602.2 66.73 GAS LIFT 5.390 31AZ' Camco KBMG GUM 91 L-80 CAMCO KBMG 2.920 EUE 8m 13,429.0 6,339.1 70.22 GAS LIFT 5.390 312"x 1-Camco KBMG GUM CAMCO KBMG 2.920 13,519.2 6,369.0 70.98 NIPPLE 4.500 HIES NIPPLE wl 2.813-X PROFILE HIES CPAI 2.813 pan# 1'60612 3,"X"line M10141 8333 Ct]0N 05 14,975.3 6,714.5 81.79 GAUGE 4.915 SUB SOLID GAUGE MANDREL Scblum- PN1006 2.913 (SGM) wI ENCAPSULATED I -WIRE Camco 34337, wI CANNON CLAMPS se,# CYGM- 0236 15,025.9 6,721.6 81.85 SEALASSY 4.500 BAKER 80 OLOCATOR SEAL Baker GBH 22 3.000 ASSEMBLY(-18' for Seal Travel) burned (1.29' Up) seal assembl y-PN: H450-01 -4081, con Mandrel Inserts : excludes pulled inserts a, an Top III TopINO) (MEN Top on Inal l°) Na n sery Valve Type LNCM1 Type OD (in) T0.0 0.un (psi) Run Dale Cam6keModel Ppl Slie gn) 5,910.3 3,391.2 6675 GAS LIFT GLV BK 1 1753E 2I2612013 0,188 11,514.9 5,602.2 66.]3 2 GAS LIFT GLV BK 1 1,288.0 2/2612013 0,188 13,429.0 6,339.1 70.22 3 GAS LIFT OV IRK 1 0.0 2/2112013 0,250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... GD Top lrvD) TopMa Nominal Ni ID Top (Ron IMLB) (°) tom Des (in) Cam Make Modll Ped 14,992.7 6,716.9 81.87 PACKER 6.550 BAKER PRO ZXP LINER TOP Baker Oil PN:H296- 4.940 PACKER Tool 31-0229 15,011.7 6,719.6 81.86 XO THREAD 5.500 XO Sub 51,7' 15# TSH 563 box x 4.950 TSH 521 box 15,013.2 6,719.8 81.86 NIPPLE 5.500 BAKER RS NIPPLE Baker Oil PN:H294- 4.880 Tool 01-0154 15,025.6 6721.6 81.85 XO THREAD 5.500 XO 5.55 PC" 15#TSH 521 box 4.950 5" 15# TSH-521 box 15,045.8 6,724.5 81.84 XO Reducing 5.000 CROSSOVER 5"x4.5" 4.500 15,144.4 6,738.8 81.21 NIPPLE 4.500 HESXN NIPPLE w2.666-NO GO HESX 2.813 2.660 line leading nipple, 2666 nogo ID, ser# G269105 15,369.5 6767.4 85.03 Swell Packer 6.3]5 FREEPACKI 1S1-11 SWELL TAM PN:450.FR 3.908 PACKER wf 6.5'OD Inlerralio -02- CENTRALIZER His, 10063900, SIN 50111198-2 WNs PROD WELLNAME CD3-119 WELLBORE CD3-119 ConocoPhillips Alaska, Inc. HANGER 11,1 HANGER GUM75 HANGER X�S CONDUCTOR. S".0-11A.1 FLOAT COLLAR. 3.574.6- CRAP STAGE COLLAR. 8.327.� ACCAP NIPPLE 13,510.2 GAUGE 14M3- HANGER, 15,015.7-15, FLOAT COLLAR, HL1A%1 PERFP PEREP Perforations & Slots OD IBTM Box )KI F50-1 w16.5.OD Box x IBTM Pin ! " # " $ % &' ( )$! * (% +, !- ."! ! /, +, 01 021*- 1 3 + - " ( % /45*2 ! )4**0 ! & % /452. 64//5 )4**0 )4** ! "# $% & '( &)&!*#&))"* + 744 - 528 ,#.1 216)9:% )4*069;% < ;+ (4 - < 8= %8>?, < 6//59:% )**9;% ;# :??#2& 05//9:% 4//*9;% 0 @7 ( $ + - 5 @ 2" < % ( " &' ( % , ( )" < A "%, & % A A$!B C,CA (! !3 &' :< ! :< 7 & & < D +/1*-0)5#5*.0 )+!%*# ) "%* &%""*# &%,"* &"""*# &","* '( &)+&#&)+ * &) $#&) $* &)&,#&)&%* 0 ! ! & & - 06.6 )*25 )**0 )8 1*28 *)028 628 . .19 5)5/9 201.9 $ , 7 7! 6 +@ 01 021*14021*4E020.5- 2 % ! 5/* *$( ( (< !3 060 /0 3 ! < A #: B < 1 65)29 1 // C %5#/ &,F ,F$,!%A !& ;$! ::$$! 2342' 45 /61 27 83.. 432 '41/ , ,#"") "# "%#,"& %#""#"" !3 4 - ""%&" $$ " )/* 5 6" G " < 0. % ( $ H % 06/5*0 %,5*01645*01245)66*145)66*45)66*0 122 )/ #G < /52. "$!B"A .2 " #G ) 5)21 2060 '( ) 1#616 530101 " 51( By Samantha Carlisle at 11:05 am, Apr 13, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.04.13 09:53:53 -08'00' SFD 4/15/2021 RBDMS HEW 4/15/2021 Alpine Oil Pool DSR-4/14/21VTL 5/5/21 SFD 4/15/2021 CD3-119 Summary of Operations Perforations DTTMSTART JOBTYP Summary OPS 3/16/2021 ZONAL Perforate with 2.0" PJ Omega 6spf 60 deg phasing from 17,483'-17,503' RKB. 3/17/2021 ZONAL Perforate with 2.0" PJ Omega 6spf 60 deg phasing from 16,300’-16,320' RKB. 3/17/2021 ZONAL Perforate with 2" PJ Omega 6spf 60 deg phasing from 16,000'-16,602' RKB. JOB COMPLETE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD3-119 ninam Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: FCO / Add Perf 3/17/2021 CD3-119 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 36.5 Set Depth (ftKB) 3,650.4 Set Depth (TVD) … 2,483.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 34.3 Set Depth (ftKB) 15,242.7 Set Depth (TVD) … 6,753.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 14,992.7 Set Depth (ftKB) 19,358.0 Set Depth (TVD) … 6,771.7 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 14,992.7 6,716.9 81.87 PACKER BAKER HRD ZXP LINER TOP PACKER 4.940 15,013.2 6,719.8 81.86 NIPPLE BAKER RS NIPPLE 4.880 15,015.7 6,720.2 81.86 HANGER BAKER FLEX LOCK LINER HANGER 4.880 15,027.3 6,721.8 81.85 SBE BAKER 80-40 SEAL BORE EXTENSION (Effective Seals 18.5') 4.000 15,045.8 6,724.5 81.84 XO Reducing CROSSOVER 5" x 4.5" 4.500 15,144.4 6,738.8 81.21 NIPPLE HES XN NIPPLE w 2.666" NO GO 2.660 15,369.5 6,767.4 85.03 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/ 6.5" OD CENTRALIZER 3.908 15,425.4 6,771.7 86.25 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/ 6.5" OD CENTRALIZER 3.908 17,909.2 6,733.0 90.59 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/ 6.5" OD CENTRALIZER 3.908 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.3 Set Depth (ft… 15,046.1 Set Depth (TVD) (… 6,724.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.3 31.3 0.00 HANGER FMC TUBING HANGER 4.500 145.4 145.4 0.91 XO Reducing CROSSOVER 4.5 x 3.5, #9.3, L-80, EUE8RD3.500 2,399.3 1,997.4 64.04 SAFETY VLV CAMCO TRMAXX-5E w/ 2.812" X PROFILE w/ 1/4" CONTROL LINE 2.812 13,519.2 6,369.0 70.98 NIPPLE HES NIPPLE w/ 2.813" X PROFILE 2.813 14,975.3 6,714.5 81.79 GAUGE SLB SOLID GAUGE MANDREL (SGM) w/ ENCAPSULATED I- WIRE w/ CANNON CLAMPS 2.913 15,025.9 6,721.6 81.85 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY (~18' for Seal Travel) (1.29' Up) 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 15,810.0 15,815.0 6,769.8 6,769.6 4/19/2012 1.0 PERFP 16,000.0 16,020.0 6,763.3 6,762.5 3/17/2021 6.0 APERF 2" Power Jet Omega 16,097.0 16,102.0 6,760.6 6,760.5 4/19/2012 1.0 PERFP 16,300.0 16,320.0 6,759.2 6,759.0 3/17/2021 6.0 APERF 2" Power Jet Omega 16,379.0 16,384.0 6,759.2 6,759.3 4/19/2012 1.0 PERFP 16,703.0 16,708.0 6,762.1 6,762.1 4/19/2012 1.0 PERFP 16,982.0 16,987.0 6,760.5 6,760.4 4/19/2012 1.0 PERFP 17,257.0 17,262.0 6,752.4 6,752.3 4/19/2012 1.0 PERFP 17,483.0 17,503.0 6,746.2 6,745.5 3/16/2021 6.0 APERF 2" Power Jet Omega 17,539.0 17,543.0 6,744.0 6,743.8 4/19/2012 1.0 PERFP 17,820.0 17,825.0 6,734.4 6,734.3 4/19/2012 1.0 PERFP 17,962.0 17,966.0 6,732.2 6,732.1 4/19/2012 1.0 PERFP 18,677.0 18,682.0 6,751.7 6,752.0 4/19/2012 1.0 PERFP 18,994.0 18,999.0 6,762.2 6,762.4 4/19/2012 1.0 PERFP 19,311.0 19,316.0 6,770.2 6,770.3 4/19/2012 1.0 PERFP Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 2/13/2013 15,810.0 19,316.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,910.3 3,391.2 66.75 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,753.0 2/26/2013 2 11,514.9 5,602.2 66.73 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,288.0 2/26/2013 3 13,429.0 6,339.1 70.22 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/21/2013 HORIZONTAL, CD3-119, 4/13/2021 8:59:00 AM Vertical schematic (actual) LINER; 14,992.7-19,358.0 PERFP; 19,311.0-19,316.0 PERFP; 18,994.0-18,999.0 PERFP; 18,677.0-18,682.0 PERFP; 17,962.0-17,966.0 PERFP; 17,820.0-17,825.0 FRAC; 15,810.0 PERFP; 17,539.0-17,543.0 APERF; 17,483.0-17,503.0 PERFP; 17,257.0-17,262.0 PERFP; 16,982.0-16,987.0 PERFP; 16,703.0-16,708.0 PERFP; 16,379.0-16,384.0 APERF; 16,300.0-16,320.0 PERFP; 16,097.0-16,102.0 APERF; 16,000.0-16,020.0 PERFP; 15,810.0-15,815.0 INTERMEDIATE; 34.3-15,242.7 SEAL ASSY; 15,025.9 GAUGE; 14,975.3 NIPPLE; 13,519.2 GAS LIFT; 13,429.0 GAS LIFT; 11,514.9 GAS LIFT; 5,910.3 SURFACE; 36.5-3,650.4 SAFETY VLV; 2,399.3 CONDUCTOR; 36.0-116.0 HANGER; 31.3 WNS PROD KB-Grd (ft) Rig Release Date 4/23/2012 CD3-119 ... TD Act Btm (ftKB) 19,375.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032065300 Wellbore Status PROD Max Angle & MD Incl (°) 92.68 MD (ftKB) 17,622.86 WELLNAME WELLBORECD3-119 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 17,483.0 17,503.0 6,746.2 6,745.5 3/16/2021 6.0 APERF 2" Power Jet Omega 16,000.0 16,020.0 6,763.3 6,762.5 3/17/2021 6.0 APERF 2" Power Jet Omega 16,097.0 16,102.0 6,760.6 6,760.5 4/19/2012 1.0 PERFP 16,300.0 16,320.0 6,759.2 6,759.0 3/17/2021 6.0 APERF 2" Power Jet Omega 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. al Q - 007 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESC N: OVERSIZED: NOTES: olor Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other:BY: (Maria � 9 Date: /� PIP /s/ Project Proofing BY: 411210 Date: /s/ 1 91/7/141. air I Scanning Preparation (p x 30 = ` 3 d + I 7 =TOTAL PAGES I / 7 ell. ' (Count does not include cover sheet) BY: Date: 1C/Ipt. /s/ MPProduction Scanning ! Stage 1 Page Count from Scanned File: I t U (Count does include covers et) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: Vtilitt. /s/ imp Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o M p 9 O a) LL N 9 o v p r CO o Q_ N CD �O � LL to Z I � � � IN L ` OON o o E -o'o UT j 4.1. a v o maN rn a a .ov LO . o + LL >. N to vU p a v Z ZCY V t N CC a Q -c) W Q TOI (a N [C — a) CY a > a s ca c o w LL O_ c o — m Cl) O o g Q = coo 0 c . '� CC 0 -o c cc rn y CL as O L 2 O 0 C V_1 O ¢ > > W oo OO Si Ze- 'E J a O_ o = O =g O w n C9 co E c E. p > . cnY yE � = OQ = W o 0/CO v w/ J a) p > a) CO CO CO 0 p S U' .) U O N ` D_ c y N N N N N N N N N CO N N a �, J Q. J U a) a J a > 0 0 0 0 0 0 0 0 0 0 0 o Ey E W :° N N N N N N N N N N N N CO 7 I C LO U) M CO U) U) It) CO In t1) Cl) Z N p, a) a) N N N '- N N N N N N N 13 0 c c c c c c c C C C C c .O W z J I x a a a) Cl) a) a a a Cl) a a a a) V U p 000000000 0000 O y Z as v wa ^ N M_ M _M coLo ' Ce O M M ^ O (O V7 (D N N CO M N E 7 ) N co co (O r r r r r r J^ a m Z „ CLQ of a) M c Z C t+ N co O O O O O (0 O d G r O ate+ N in LC) LO 1� O (OD (�O COO (O CO CO fDCO O H N (O CO CO CO CO M CO O N a a) ti E a i N U N m U m o M CL Z to Q t] a Ua p p)v O 5~ p CV o J41) 2 0 0 0 0 0 0 0 i6 0 /G� al NCV 1 N co co W Li, re d' J 4) N N N N N N N C Jt ''^^ J +o V/ • 0 U) Q Jc U g Q T) c 21 co 0 Z Eo w w > w w .>` w m 0 o > '> > > > '> '> > EJ a' I c N H U h N N N 74N . Z 7 U 0 0 O_ y CY C.00 0_ U a) d +) C C C C C C C C C CV E E99 • 29 >, 0 0 0 0 o E co co > 0 0 m 0 > c a 0 z 33 w v as aa Cr) c o Q E E Q o E 0 C \c E 0CI p O J a) d o 8 W c b yr a v co c >— m o 2 E . v W N 0 .2 WOZ N N aa)) W OLL Ii ! „c C] LO r C co c co C] y \W— �� \ A o o �jcL E 0 C='J a m °) a a o o O O O 0 o n. 0 0 y OLL Q LL CL 0 H 3 3 o 1 a' J J a J J J J J CY W W 3 Z o I I rn 0 o N O M 0� Z N V) Z >- r ClCil U N a a> 0) 0) < -coo o -uZ 0 _ a a m a 2 m , 0 0 -J 0 Z ." ci o - lb: c. 0 Ce Q E O i OIl ‘5 Ta m Il CL a EL W z - N N J N 01 a V0 O E LI E Z m 0 r Q 0 0) M J a C 0 = v E 1 J 0. co = o 0 a 2 0 0 • co o O N a VN : ii 0)Ca Ce E re v o 1— E W �p = Vn 0 U a) p I 0 c Q J c O CO N- N p I— U o • a Q c E •5 m O Z o > E 0 D 2 TT, 0co Z N N 1 ai n Q N N M M 64 0 NCV C I T V O TQ' '3 o CO N E o _O d N r I N a — 2 ai a>i N e- a3 M 0 0 w c ay D c o 2 Z c as o t. u p o p U .+ .7.I _) y a a) co n o o a m 0 E a p y 0 E 2 rc as 0 o a d o E Q a 2 0 a 0 1 U 0 c 0 U 1 0 • RE, STATE OF ALASKA IVIED A KA OIL AND GAS CONSERVATION COI.....,SSION MAR 0 8 2013 REPORT OF SUNDRY WELL OPERATIONS /�/� 1.Operations Performed: Abandon Repair w ell r Plug Perforations Perforate O Other FGCC Alter Casing r Pull Tubing r Stimulate-Frac ( Waiver r Time Extension r— Change Approved Program j`Operat. Shutdown r Stimulate-Other E Re-enter Suspended Well r..- 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development { Exploratory E . 212-007 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 - 50-103-20653-00 7.Property Designation(Lease Number): 8.Well Name and Number; ADL 372105,372104,364470,364471,364472 - CD3-119 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Colville River Unit/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 19375 feet Plugs(measured) 13519' true vertical 6772 feet Junk(measured) none Effective Depth measured 19358 feet Packer(measured) 14993 true vertical 6772 feet (true vertical) 6717 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 116' 116 Surface 3614' 10.75" 3650' 2484 Intermediate 15208' 7.625" 15242' 6753 Liner 4365' 4.5" 19358' 6772 Perforation depth: Measured depth: pup liner 15810-19316 True Vertical Depth: 6768'-6770' Tubing(size,grade,MD,and TVD) 3.5, L-80, 15046 MD,6725 ND Packers&SSSV(type, MD,and TVD) PACKER-BAKER HRD ZXP LINER TOP PACKER @ 14993 MD 6717'ND SSSV-CAMCO TRMAXX-5E SSSV @ 2399' MD and 1997'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 15810'-19316' Treatment descriptions including volumes used and final pressure: 636934#of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 688 1648 7 _ -- 289 Subsequent to operation 3233 2464 192 -- 385 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory 1— Development 1 - Service r Stratigraphic 16.Well Status after work: - Oil J Gas r WDSPL Daily Report of Well Operations_XXX GSTOR E WINJ r WAG E GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-023 Contact Robert Blakney @ 265-6417 Email Robert.G.BlakneyCc�conocophillips.com Printed Name Robe _,:lak Title Completions Engineer 3 / 7/7 3 Signature ,/ / Phone:266-6417 Date IDMS MAR 0 8 2013 VH /4 Form 10-404 Revised 12/2012 4/1Z/ 13 Submit Original Only w , WNS CD3-119 ConocoPhillips4.4‘004Well Attributes Max Angle&MD TD AlaSl(a,1fIC.. Wellbore APUUWI Field Name Wellbore Status Ind(*) MD(ORB) Act Dim OMB) 501032065300 FIORD NECHELIK 9268 17,622.86 19,375.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••Well Confq:HORIZONTAL-CD3-119,2/21/2013 9:52:44 AM -SSSV:TRDP Last WO: 4/23/2012 Schematic-Accuai Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/0,SET PLUG,FRAC haggea 2/18/2013 HANGER,31 Casing Strings Casing Description String 0... String ID...Top(0KB) Set Depth(f...Set Depth(ND)... String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 -String H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 36.5 3,650.4 2,484.4 45.50 L-80 BTCM CONDUCTOR, Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 36-116 INTERMEDIATE 75/8 6.875 34.3 15242.7 6,753.0 29.70 L-80 BTCM 1-3 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...-String...String Top Thrd LINER 41/2 3.958 14,992.7 19,358.0 6,771.7 12.60 L-80 IBT-m lner Details Top Depth SAFETY VLV, 4 I 'I (ND) Top Incl Nomi... 2'388 I a Top (RKB) (ftK8) (°) Item Description Comment ID(in) 14,992.7 6,716.9 81.87 PACKER BAKER HRD ZXP LINER TOP PACKER 4.940 SURFACE,_--A L 15,013.2 6,720.8 82.61 NIPPLE BAKER RS NIPPLE 4.880 37-3,850 15,015.7 6,721.1 82.58 HANGER BAKER FLEX LOCK LINER HANGER 4.880 GAS S 610 15,027.3 6,722.5 82.46 SBE BAKER 80-40 SEAL BORE EXTENSION(Effective Seals 18.5') 4.000 ilIl 15,045.8 6,724.8 82.26 XO Reducing CROSSOVER 5"x 4.5" 4.500 15,144.4 6,737.4 78.89 NIPPLE HES XN NIPPLE w 2.666"NO GO 2.660 15,369.5 6,766.3 84.52 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 15,425.4 6,771.7 86.24 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 GAS LIFT, 1 17,909.2 6,733.0 90.59 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 11,515 Tubing Strings OAS LIFT.H Tubing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)...String Wt...String... String Top Thrd 13.428 TUBING 31/2 2.992 31.3 15,046.1 6,724.8 9.30 L-80 EUE8RD Completion Details PLUG,13,519 Top Depth - NIPPLE,13,519 (ND) Top Incl Nomi... Top MB) MB) (•) Item Description Comment ID(in) 31.3 31.3 -0.02 HANGER FMC TUBING HANGER 4.500 145.4 145.4 0.36 XO Reducing CROSSOVER 4.5 x 3.5,#9.3,L-80,EUE8RD 3.500 2,399.3 1,997.1 64.04 SAFETY VLV CAMCO TRMAXX-5E w/2.812'X PROFILE w/1/4"CONTROL LINE 2.812 GAUGE,14,976-- t 13,519.2 6,369.0 71.16 NIPPLE HES NIPPLE w/2.813"X PROFILE 2.813 �� 14,975.3 6,714.5 81.88 GAUGE SLB SOLID GAUGE MANDREL(SGM)w/ENCAPSULATED I-WIRE w/ 2.913 = CANNON CLAMPS 15,025.9 6,722.3 82.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY(-18'for Seal Travel)(1.2w 3.000' Up) I E r Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY. Top Depth 15,026 (ND) Top Incl Top(RKB) IRKS) Ii Description Comment Run Date ID(in) 13,519.2 6,369.0 71.16 PLUG 2.81 XX PLUG IN X-NIP 2/17/2013 Perforations&Slots I Shot Top(ND) Bon(TVD) Dens Top(MB)Bim(MB) (MB) (RKB) Zone Date Oft.. Type Comment 15,810.0 15,815.0 6,768.3 6,768.3 4/19/2012 1.0 PERFP 16,097.0 16,102.0 6,759.1 6,759.2 4/19/2012 1.0 PERFP LATER 34-16243 ° • • 16,379.0 16,384.0 6,759.2 6,759.3 4/19/2012 1.0 PERFP 16,703.0 16,708.0 6,761.8 6,761.9 4/19/2012 1.0 PERFP III16,982.0 16,987.0 6,760.5 6,760.3 4/19/2012 1.0 PERFP __-- 17,257.0 17,262.0 6,753.8 6,753.5 4/19/2012 1.0 PERFP 17,539.0 17,543.0 6,744.0 6,743.8 4/19/2012 1.0 PERFP 17,820.0 17,825.0 6,732.3 6,732.4 4/19/2012 1.0 PERFP PERFP, II 17,962.0 17,966.0 6,732.0 6,731.9 4/19/2012 1.0 PERFP 15,815,810-15,81515, 5 '1 IF 18,677.0 18,682.0 6,750.3 6,750.7 4/19/2012 1.0 PERFP PERFP. _ ® 18,994.0 18,999.0 6,762.0 6,762.2 4/19/2012 1.0 PERFP 16,097-18,102 - 19,311.0 19,316.0 6,770.1 6,770.3 4/19/2012 1.0 PERFP PERFP' 18,379-16,384 . ® Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) IND) (ftK8) (ftKB) (RKB) (RKB) Type Date Comment 16,701PERFP,8 - 11 II15,810.0 19,316.0 6,768.3 6,770.3 FRAC 2/13/2013 Pumped to completion plating 636,934#of 16/20 propant behind pipe(100%of design) PERFP, 16,982-18,987 - " PERFP, __ • 17,257-ERFP. ..- PERFP. 17,539-17,543 , FRAC,15,810 -- PERFP, Mandrel Details 17,020-17.825 a 115 1 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run N...Top(RKB) (RKB) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 5,910.3 3,391.1 66.57 CAMCO KBMG 1 1/2 GAS LIFT DMY BK 0.000 0.0 2/3/2013 2 11,514.9 5,602.4 66.98 CAMCO KBMG 1 1/2 GAS LIFT DMY BK 0.000 0.0 2/3/2013 3 13,429.0 6,339.1 70.53 CAMCO KBMG 1 1/2 GAS LIFT DMY BK 0.000 0.0 2/4/2013 PERFP, ,.. ■ 17,982-17,988 PERFP, , 18.877.ERPF ■I. PERFP, 113.994-113,999 PEERFP,RFP. Be 19.311-19,310 LINER, • i® 14,993-19,358 TD(CD3-119),-\ 19,375 CD3-119 Frac Summary DATE SUMMARY 2/2/2013 SET XX PLUG @ 13,519' RKB. PULLED OV @ 13,429' RKB AND GLV @ 11,515' RKB. IN 2/3/2013 SET DV @ 11,515' RKB. PULLED GLV AND SET DV @ 5910' RKB. READY TO CIRC-OUT. 2/4/2013 SET DV @ 13,429' RKB. MITT:PASSED MITIA:PASSED EQUILIZED XX-PLUG @ 13,519' 2/5/2013 PULLED XX-PLUG @ 13,519' RKB. BELOW MIN TEMP. IN PROGRESS. 2/6/2013 SET FRAC SLEEVE @ 2399' RKB. GAUGED/BRUSHED TREE. READY FOR FRAC. 2/13/2013 Performed frac treatment of the Nechelik, pumped to completion placing 636,934 lbs of 16/20 proppant behind pipe (100% of designI,ail filum-&reeze protect away. Had difficulties mairitammg network communication between pump operation controls and pumps throughout job, causing pumps to intermittently shut down. Well left secured with riser disconnected at ground due to late 2/16/2013 PULLED FRAC SLEEVE f/2399' RKB. ATTEMPT TO TAG FILL, STALLED OUT @ 15119'. IN 2/17/2013 SET 2.81 XX- PLUG IN X-NIPPLE @ 13519' RKB. IN PROGRESS 2/20/2013 PULLED DMY f/ST.#3 @ 13429' RKB. GOT HUNG UP IN SSSV&CLIPPED WIRE. RECOVERED TOOL STRING. IN PROGRESS. 2/21/2013 SET 1"OV IN STA. 3 @ 13429' RKB. PULLED 1" DMY VLV f/STA.2 @ 11515' RKB. IN 2/26/2013 PULLED DMY @ 5910' RKB, REPLACED WITH 3/16"GLV, SET 3/16"GLV @ 11,514' RKB, TESTED GAS LIFT STRING TO 1500 PSI GOOD TEST. IN PROGRESS. 2/27/2013 PULLED XX PLUG @ 13,519' RKB, SET FRAC SLEEVE @ 2399' RKB. READY FOR FLOW 3/4/2013 PULLED FRAC SLEEVE @ 2399' RKB. GOOD CLOSURE TEST ON SSSV. ��\V/7id s. THrE STATE Alaska Oil and Gas •� —W. IIIALAS� Conservation Commission `� GOVERNOR SEAN PARNELL 333 West Seventh Avenue *h. O mR9 Anchora e Alaska 99501-3572 1� ALAS Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney Completions Engineer ConcoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 l g-�Q d a 7 Re: Colville River Field, Fiord Oil Pool, CD3-119 -- � Sundry Number: 313-023 Dear Mr. Blakney: 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, 1/-2—)1-e--(4/1"-- Cathy P. oerster Chair DATED this 3U'day of January, 2013. Encl. II , Ft pm D • STATE OF ALASKA I Z12._5. 1,340-45ALASKA OIL AND GAS CONSERVATION COMMISSION 4S JAN 18 201'3 APPLICATION FOR SUNDRY APPROVALS U,0 /� 20 AAC 25.280 if AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r lime Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r• Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development r. Exploratory r 212-007 • 3.Address: • Stratigraphic[ Service r 6.API Number:So../01-.to6Sb-00-00 P.O.Box 100360,Anchorage,Alaska 99510 5 403-26655 114A 7.If perforating, 8.Well Name and Number: i/)�L 3 What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes fl No F CD3-119, 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,372104,364470,364471,364.472 Colville River Unit/Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): -19375 6772 • 19358' 6772' none none Casing Length Size MD TVD Burst Collapse Conductor 80 16" 116' 116' Surface 3614' 10.75" 3650' 2484' • Intermediate 15208' 7.625" 15242' 6753' Liner 4365 4.5" 19358' 6772' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): pup liner 14993-19358 6717'-6772' 3.5 L-80 15046 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER HRD ZXP LINER TOP PACKER - MD=14993 TVD=6717 SSSV-CAMCO TRMAXX-5E ' MD=2399 TVD=1997 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program (- BOP Sketch r Exploratory r Stratigraphic r Development r• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/25/2013 Oil r - 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: Robert Blakney @ 265-6417 Email: Robert.G.BlaknevCciconocophillios.com Printed Name obert Blakney Title: Completions Engineer /� Signature Phone:266-6417 Date Commission Use Only n Sundry Number:31 3- Conditions of approval: Notify Commission so that a representative may witness 023 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS JAN 311013 Spacing Exception Required? Yes ❑ No U Subsequent Form Required: l — 4 // Approved by: 95-t-4W----- APPROVED BY `�COMMISSIONER THE COMMISSION Date: I - 3 n- /3 Approved application is valid for 12 months'from the date of approval. Form 10-403(Rev ed 10/2012) Submit Form and Attachments in Duplicate ORIGINAL CD3 — 119 Sundry Application CD3 -119 was completed in April of 2012 as horizontal producer in the Nechelik formation. The well was completed with 3.5"tubing and a 4.5" liner with 4 sections of perforated pup joints, we will drop bio balls during the 4 stage treatment to achieve frac isolation. We expect the increased production to be 150 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 11 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater(approx. 4900 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 200 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7500 psi. Stage 1 • 310 bbls YF125ST Pad • 150 bbls YF125ST w/2 ppa 16/20 Carbolite • 450 bbls YF125ST w/4 ppa 16/20 Carbolite • 350 bbls YF125ST w/7 ppa 16/20 Carbolite • Bioball diversion Stage 2 • 310 bbls YF125ST Pad • 150 bbls YF125ST w/2 ppa 16/20 Carbolite • 450 bbls YF125ST w/4 ppa 16/20 Carbolite • 350 bbls YF125ST w/7 ppa 16/20 Carbolite • Bioball diversion Stage 3 • 310 bbls YF125ST Pad • 150 bbls YF125ST w/2 ppa 16/20 Carbolite RB • 450 bbls YF125ST w/4 ppa 16/20 Carbolite • 350 bbls YF125ST w/7 ppa 16/20 Carbolite • Bioball diversion Stage 4 • 340 bbls YF125ST Pad • 150 bbls YF125ST w/2 ppa 16/20 Carbolite • 350 bbls YF125ST w/4 ppa 16/20 Carbolite • 250 bbls YF125ST w/6 ppa 16/20 Carbolite • 250 bbls YF125ST w/8 ppa 16/20 Carbolite • Flush with 142 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 640,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) Production Casing Cement Report: CD3-119: 7 5/8" casing cement pump report on 3/23/2012 shows that the job was pumped as designed, indicating competent cementing operations. A balanced cement plug was pumped with 12.5 ppg mud push and 17 ppg class G cement and displaced with 10.5ppg mud. CD3-301: 7" casing cement pump report on 3/26/2010 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with 15.8 ppg cement and displaced with 10.5 ppg mud and the plug was bumped as designed. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a1/4 mile radius or any other nearby well. RB Stimulation Surface Rig-Up ck r?Ieed r Tattle \ ( I Tale Tank 1'41"1 10 I- m n dg 1:1 • Minimum pressure rating on all surface treating lines 10,000 psi )&11111 1=rl80 • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi C • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. g 1104 m y� ►•416,1 4aruj awed cr3 Pap-OIf Tank O D84—Pop-Off Ta* Pump Trur.* It Ct. 41 10 r N Frac Pump +14—D811— —Da '►J Frac Pump Frac Pump -- — `f--1-1.. Frac Pump Frac Pump '+'41-1)81.1— --Ca IT,1 Frac P unp RB Stimulation Tree Saver OPEN POSITION CLOSED POSITION )PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) t l � FRAC IRON i • CONNECTION I II � i [ , [ 4..C.....1 TT. : ,REMOTE OPERATED ,,�TT MASTER VALVE M IAN ( •)�( MANUAL OPERATED A+ MASTER VALVE olmit sons. / ( Stinger MANDREL ( 1 .1 lir El T ` I / I \ VENT t .: ®1.111--.—VALVE � OPEN Ila' /iii ■� y 20— :4; ll ':01.I .' . �[. FLOW TEE AND Ii',,■%4. VENT VALVE WELLHEAD 1.1 Fall VALVES ,//-::•X./i OPEN III " ---r. ,s, y uu ti WELLHEAD J^, 11—' : VALVES ',' CLOSED ` �� ::9* '' '"' ". •' . `P---s PACKOFF I ..� • ASSEMBLY IN i, f♦ PLACE IN TUBING ... • TUBING g� �. • [ • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25"down 4 '/2 tubing and 1.75"down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm RB Well Schematic: ,1i WNS CD3-119 ConocoPhillips Well Attributes Max Angle&MD TD l wenta'e AFCUdI Flela 1311e N'!i:S1ala not 1': MD.It B1 Act31rr IMP:.,>.SiSB_IOC SIl :-,_:3,6 Ai': ri.:1I;O':. :L 1:. '11:C.:,L'_' :2.56. 7 522 85. '9,375 C Comrent 'H_:'Dort Date Ar icle1ion End Cate 143.0rot IRF Pig Release Date vwu :.,r.r rG I7OSIT3 -^79.10•t'.n'2d12 1,4414 MA SSSV TRDr y.17J_t 4.23':312 B nerashc-*mei Annatat an tCealr:Rr.a: Enc:me AnroW7br Last W aC End late -_asl Tay Itee Keri.,...DRILL DrTE;,`'EKES .:.n 11:292012 Casing Strings -. Cas no Deco-t ticn Strnp 0... Serino-:... Too elh31 Set Depth r'... Set Croft-;-.'C.... Sr np'1t ming St-np-op-hra �JNr,.CTJI1 '6 'S 0112 36.0 "50 '6.0 5250 )14S WE-DED Cas ng Ces,lptlen Strnp C•_. Serinp : Top OW 31 Set Depth r'...Set Capps!repo... Strnp Mt._String. Strew rep Tera SURFACE '0'i.•1 . :i0 36.5 3.65:1 2.484 4 45.50 L80 BTCM 03‘.0 lee , Cai'np Cecorl teen Strnp 0,.. Strinp :... Too rtttt31 Set Depth in,.. Set°cobs 1TVCl... erne wit-.String Strnp Tap Thrd 34 tip sN'EFtIAEG.7\TE 5.11 •i 175 31.3 `5242.7 5.7530 29.70 L 80 BTCM __ . Cas+np IDAE:A ler St•np C•... Strinp ... Too I 31 Set Depth it... Pet Coolh 1TVCl... Sbtnp Wt..String"- Steno Top Tera { J'.=' 1 •.... ..._55 119_2.7 9 358.0 6.77'7 12.60 L80 :BT-in 1 A Liner Details 'op Dieser 5A=ETT vtsi, t _� INC': Top Ira 3"/! L, Norm... r I Tao r'W.81 FhK81 tp. eaM asaw+gdlen comment ID fM1 n 1.992 7 6,715.9 81 87 PACKER BAKE1 r'RD ZXr LNEt TOP PACKER 4 940 5.31:1 2 6,720.8 82 61 NIPPLE BAKER RS N:PP_E 4 880 SLRFACE, 37.3 esc 5,715 7 6,721.1 82 58 HANGER BAKER FLEX LOCK LINER.HANGER 4 880 NS uEr• -� - 5.727 3 6,722 5 82 46 SBE BAKER 80-40 SEAL BORE EXTENSION.Eliecove Seats iB 51 4 000 5.045 8 6,724.8 82 25 XO RE•'.Ucinx1 CROSSOVER 5"x 4.5' 4 500 5.'44 4 6,737.4 76 89 N.PPLE HES XN NIPPLE w 2 666•NO GO 2 560 5,365 5 6,756.3 84 52 Swop Pad.e, FREEPACK 1 FSC 11 SWELL PACKER w,"55"OD CENTRAUZER 3 908 5.425 4 6,771.7 86 24 Swell Pas7te• FREEPACK 1 FSC.11 SWELL PACKER wi 6 5"GO CENTRALIZER 3 908 GAS UPT, 1,,. 7':"i 2 6,733:' 92 59.swell Pacfter rREEPAC C rsc'I S'A'E__PICKER w15 5"OOCENTRA'_I_CR 3 908 11.515 1 . 1 Tubing Strings 1 .-32 -it ng Ce.:"rIi': St"1g 0... S7rIno = Tca t1.31 Set Depth l'...Set Dept.lreCI... Sung Mt..Steno Strip Top Tent 1;a39 i OM LIP. 1` T_C N:.: :i _ _ 3 I.3 5 346.1 6.724 F. 9.32 L 80 C,E8RD Completion Details roe 000t1 hIPP.E 13.519 L1 11111 (T.'C:' Top Ara r-._a Top 110:31 ntl181 t� Rem Desorsrilon Comment 10 ON 3s" 31 3 0 02 HANGER 6140 TUBING HANGER 41, 4 500 ^45 4 145 4 036 XO Reducing CROSSOVER 4 5 x 3.5,19.3,L-80 EUE8RD f 3 500 I'- OALOE 14 91.5 _i 2.399 3 1,997.1 64 04 SAFETY VLV CAMCO TRMAXX-SE Iv;2 812"X PROFILE tel 174"CONTROL LINE 2 812 3,519 2 6,369.0 71 16 NIPPLE HES NIPPLE nt'2.813'X PROFILE 2 813 '4,975 3 6,714.5 81 88 GAUGE SLB SOLID GAUGE MANDREL{SGMI we ENCAPSULATE' '.i RE re' 2 913 CANNON CLAMPS 5.025 5 6,722.1 82 47 57-AL ASSY BAKER 80.40 LOCATOR SEAL ASSEMBLY t- kr 518'k ..a-1 nr&:'129 3'700 U01 Amy.AT, LL Perforations& Slots , tSAtE (....___.1 - Shot Too ITYDI Ben ITV:t Cans -op IRKS) Bfin(RKai OW 31 mica:. Zone Date WI_ Teo* :OM-sent 15.8100 15815.0 5.7683 6,7681 4.191012 1.0 PERFP 6.097 0 16,102.0 5.759 1 6,759.2 4-191012 1.0 PERFr 1155M1 76,3790 16384.0 5.7592 6,759.7 41912012 1.0PERrr' `6.703 0 16 738.0 5.761 8 6,751.'4 4,19:2012 1.0 PERrr '6,9820 16987.0 6.7605 6,7507 4.'1512012 1.0 PERrr 1'F4M_CATP, • '7.2570 17252.0 5,7538 6,7535 4'1912012 1.0PER.Fr tP 343 '7,539 0 17 543.0 5.744 0 6,743.8 4.14;2012 1.0 P£RFr 1 7.8200 17825.0 5,7323 6,732.•: 1,192'012 1.0 P_Rrr 17,962 0 17 956.0 6,732 0 6,731.9 4.1612012 1.0 PoRrr 11101111101 18.677 0 18.682.0 6,750 3 6,750.7 4.1912012 1.0 P£I?rr i '8.994 0 18999.0 6,7620 6,752.2 1.11,2012 1.0 r_Rrr 19,311 D 19,316.0 6,770 1 6,770.3 1.19'2012 1.0 PERrr -Fr.r • • RB au 0) co Tf) "5 2 TD ... p = o Ti5 _co U N (p z L.L.L rn M a 0 • Q. tiQ o 0 0 0 0 0 O c 0_ o 0 0 0 0 0 a U o �i co cd 0 0 0 0 0 N N N N s CD CO (0 CO N d 0 0 0 Q) 2 J J J J 13 O 0 0 0 C CZ M (B (B M o Q 0 0 0 0 0 7 a) ci 0 0 0 0 0 0 cU co co co co co co 0 0 0 0 0 0 _C) C O o O a) +' , O O CO .L O O O 0 -4- 0 mo_ r) CO ti ti N d- CO CD V, 0 3 2 (T3 C"I In N Cl) LL O Ln coti CO co U • 0 (13 I— L.-- a) 0 - 0 0 0 0 0 0 x x x x x x I 1 1 U.. 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C yam,. ,-• .• ........"..( o U�: U '• o I 0 • U, D Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Wednesday, January 23, 2013 2:41 PM To: 'Blakney, Robert G' Subject: RE: CD4-05(PTD 207-155, Sundry 313-012) Fracture Stimulation Robbie, I have incorporated your update into the procedure and 313-012 will be sent on for Commissioner approval. This should be a good template for your other upcoming fracture stimulations. I have CD3-119 (PTD 212-007, sundry 313-023) fracture stimulation that will need to be updated. Thanx, Victoria From: Blakney, Robert G f mailto:Robert.G.Blakney@conocophillips.coml Sent:Tuesday, January 22, 2013 4:27 PM To: Ferguson, Victoria L(DOA) Cc: Blakney, Robert G Subject: RE: CD4-05(PTD 207-155, Sundry 313-012) Fracture Stimulation Afternoon Victoria, 1st off, sorry I wasn't able to call you to discuss these items in more detail. I've been trapped on the slope dealing with weather. But I did have a chance to talk to Ty and Randy about your meeting, and I believe the attachment should address all the concerns you have. Assuming you like addresses your concerns, I will send similar updates for the CD3 -109 and CD3- 199 sundry applications shortly. And then we can use this as the template going forward. Please let me know if you have any questions. Thanks, -Robbie Robert Blakney ConocoPhillips Completions Engineer 907-265 -6417 (office) 713-367-8504 (cell) ATO 1508, 700 G st. Anchorage, AK From: Ferguson, Victoria L(DOA)jmailto:victoria.ferguson@alaska.govl Sent: Friday, January 18, 2013 10:23 AM To: Blakney, Robert G Subject: [EXTERNAL)CD4-05(PTD 207-155, Sundry 313-012) Fracture Stimulation Robert, Several items on this procedure: 1. Provide schematics(wellhead/BOP/surface) and/or engineering statement that wellbore and surface is appropriately constructed to handle treatment pressures. 2. Engineering review and assessment of cementing in subject well and welioores within the Y mile radius. 3. Where will frac flowback be taken? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson;u alaska.gov 2 RECEIVED Halliburton JAN 16 2013 Sperry Drilling 6900 Arctic Blvd AOGCC Anchorage, AK 99518 Jan. 10, 2013 AOGCC Makana Bender 333 W. 7th Ave., Suite .8 yr Anchorage, AK 9950 ,0v Dear Sir or Mad.• t?f, ry Subject: CD3-119 CD3-128/CD1-48A/CD4-03 Definitive Survey Reports Enclosed are one hard copy (NAD83 and NAD27) of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK •0.18 Received by: " I 14,44rI Date: Please contact me at 907.263.465 with questions or concerns. Regards, ip-ou • ) - 307 Avinash Ramjit II STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q 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. or Aband.: April 23,2012 212-007/- 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 February 26,2012 50-103-20653-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3984'FNL, 1030'FEL,Sec.5,T12N,R5E,UM • April 15,2012 CD3-119 Top of Productive Horizon: 8. KB(ft above MSL): 50'RKB • 15.Field/Pool(s): 2152'FSL, 992'FWL,Sec.28,T13N, R5E,UM GL(ft above MSL): 12.8'AMSL• Colville River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 247'FSL, 1440'FEL,Sec.20,T13N,R5E,UM 19358'MD/6772'TVD . Fiord Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-388013 y- 6003793 Zone-4 19375'MD/6772'TVD . ADL 372105,372104,364470,364471,364472 TPI: x-392811 y- 6015139 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-390419 y- 6018549 Zone-4 2399'MD/1997'TVD LAS2112 18.Directional Survey: Yes E 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) 1150'MD/1142'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 _ 36' 116' 36' 116' 42" pre-installed 10.75" 45.5# L-80 36' 3650' . 36' 2484' 13.5" 1111 sx ASLite,258 sx Class G 7.625" 29.7# L-80 34' 15242' • 34' 6753' 9.875" 230 sx Class G,280 sx Class G 4.5" 12.6# L-80 14993' 19358' 6717' 6772' 6.75" pre-perf pup liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5"x3.5" 145'x15046' 14993'MD/6717'TVD pre-pert pup liner from 14993'-19358'MD 6717'-6772'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. + DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r dirk. cement plug 14816-15613' bi440 sx Class G kick-off plug 12372'-12872' / 319 sx Class G Vo-• ;:f cement plug 7856-8309' .f.(C- 291 sx Class G ` r'� t kick-off plug#2 3431'-3868' 281 sx Class G cement plug 3447'-3950' 354 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) April 12,2012 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/13/2012 6 hours Test Period--> 183 -434 0 100% 2747 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 328 psi 1070 24-Hour Rate-> 637 1750 1 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E. Sidewall Cores Acquired? Yes ❑ No ❑✓ . If Yes to either question,list formations and intervals cored(MD+TVD 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 results per 20 AAC 25.071. NONE RECEIVED MAY 212012 RBDMS MAY 2 2 2012 GCC i 0 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 24..„ S.Z3-I3 '?1/./) 914il, . G 28. GEOLOGIC MARKERS(List all formations and i. 3 encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ 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 1150' 1142' needed,and submit detailed test information per 20 AAC 25.071. K-1 14584' 6651' Top Kuparuk D 14762' 6682' Top Nechelik 15199' 6747' N/A CD3-119PB1 total depth 15613' 6870' Formation at total depth: Nechelik 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: J.G.Samuel)@ 265-6309 • 7 Printed Name L.Alvord Title: Alaska Drilling Manager V Signature 1 Phone 265-6120 Date 0'7 i / aI 1 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 WNS CD3-119 ConocoPhillips /114 Well Attributes Max Angle&MD TD Alaska Inc Wellbore APUUWI Field Name Well Status led 1°) MD(ftKB) Act Btm(ftKB) 501032065300 FIORD NECHELIK PROD 92.68 17,622.86 19,375.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date -SSSV:TRDP Last WO: 4/23/2012 Well Con99:HORIZONTAL-CD3-119,5/10/2012 8:29:01 AM Schematic-Acwal Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 5/10/2012 HANGER.3111111 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 10 3/4 9.950 36.5 3,650.4 2,484.4 ' 45.50 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...-String Top Thrd CONDUCTOR. INTERMEDIATE 75/8 6.875 34.3 15,242.7 6,753.0 29.70 L-80 BTCM 36-116 ,lievmv Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd f!p' LINER 41/2 3.958 14,992.7 19,358.0 6,771.7 12.60 L-80 IBT-m IOW Liner Details ill Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°I Rem Description Comment ID(in) SAFETY VLV. i -I 14,992.7 6,716.9 81.87 PACKER BAKER HRD ZXP LINER TOP PACKER 4.940 2,399 15,013.2 6,720.8 82.61 NIPPLE BAKER RS NIPPLE 4.880 15,015.7 6,721.1 82.58 HANGER BAKER FLEX LOCK LINER HANGER 4.880 SURFACE, [ 15,027.3 6,722.5 82.46 SBE BAKER 80-40 SEAL BORE EXTENSION(Effective Seals 18.5') -4.000 37-3,650 15,045.8 6,724.8' 82.26 XO Reducing CROSSOVER 5"x 4.5" 4.500 GAS LIT, 5,970 15,144.4 6,737.4 78.88 NIPPLE HES XN NIPPLE w 2.666"NO GO 2.660 r 1 15,369.5 6,766.3 84.52 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 l 15,425.4 6,771.7 86.24 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 17,909.2 6,733.0 90.59 Swell Packer FREEPACK I FSC-11 SWELL PACKER w/6.5"OD CENTRALIZER 3.908 `pN Tubing Strings �jl Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd GAS LIFT, ./ TUBING 31/2 2.992 31.3 15,046.1 6,724.8 9.30 L-80 EUE8RD 1,s,5 C�/ Completion Details _ Top Depth (ND) Top Incl Nomi... GAS LIFT, 13,428 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 31.3 31.3 -0.55 HANGER FMC TUBING HANGER 4.500 MN 145.4 145.4 0.36 XO Reducing CROSSOVER 4.5 x 3.5,#9.3,L-80,EUE8RD 1500 NIPPLE,13,519III 2,399.3 1,997.1 64.04 SAFETY VLV CAMCO TRMAXX-5E w/2.817 X PROFILE w/1/4"CONTROL LINE 2.812 I 13,519.2 6,369.0 71.16 NIPPLE 14,975.3 6,714.5 81.88 GAUGE HES NIPPLE w/2.813"X PROFILE 2.813 SLB SOLID GAUGE MANDREL(SGM)w/ENCAPSULATED I-WIRE w/ 2.913 CANNON CLAMPS 15,025.9 6,722.3 82.47 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY(-18'for Seal Travel)(1.25-3.000 GAUGE,14,975 Up) I l I SEAL ASSY, L 15,026 NTERMEDIATE, L A 34-15,243 MAIM Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) 1') Make Model (in) Sery Type Type lie) (psi) Run Date Com... 1 5,910.3 3,391.1 66.57 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,753.0 4/28/2012 2 11,514.9 5,602.4 66.98 CAMCO KBMG 1 GAS LIFT-GLV BK 0.188 1,788.0 4/28/2012 3 13,429.0 6,339.1 70.53 CAMCO,KBMG 1 GAS LIFT OV BK 0.250 0.0 4/27/2012 - LINER, 14.993-19,358 TD(CD3.119), 19,375 ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-119 501032065300 Sperry Drillinp Definitive Survey Report 23 April, 2012 m HALLIBURTON Sperry Drilling ConocoPhillips ,s-' Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod 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 CD3-119 Well Position +N/-S 0.00 ft Northing: 6,003,792.97 ft Latitude: 70°25'9.488 N +EI-W 0.00 ft Easting: 388,012.95ft Longitude: 150°54'44.282 W, [Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft Wellbore CD3-119 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 4/5/2012 15.74 79.84 57,346 Design CD3-119 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,589.41 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 37.52 0.00 0.00 320.00 Survey Program Date 4/23/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 89.00 550.00 CD3-119PB1 Gyro(CD3-119PB1) CB-GYRO-SS Camera based gyro single shot 2/29/2012 12:C 579.05 3,589.41 CD3-119PB1 (MWD)(CD3-119PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/26/2012 12:C 3,685.10 15,196.15 CD3-119 MWD(CD3-119) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/9/2012 12:OC 15,286.17 19,341.44 CD3-119 MWD(HES)(CD3-119) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/10/2012 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E1-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 37.52 0.00 0.00 37.52 -12.80 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 UNDEFINED 89.00 0.19 82.38 89.00 38.68 0.01 0.08 6,003,792.98 388,013.03 0.37 -0.05 CB-GYRO-SS(1) 184.00 1.41 334.93 183.99 133.67 1.09 -0.25 6,003,794.06 388,012.71 1.56 1.00 CB-GYRO-SS(1) 275.00 3.88 326.15 274.89 224.57 4.66 -2.44 6,003,797.67 388,010.57 2.74 5.14 CB-GYRO-SS(1) 369.00 5.04 327.65 368.60 318.28 10.79 -6.43 6,003,803.86 388,006.69 1.24 12.40 CB-GYRO-SS(1) 461.00 5.51 338.53 460.21 409.89 18.32 -10.20 6,003,811.43 388,003.02 1.20 20.59 CB-GYRO-SS(1) 550.00 6.83 356.01 548.70 498.38 27.57 -12.14 6,003,820.72 388,001.23 2.56 28.92 CB-GYRO-SS(1) 579.05 7.10 353.68 577.54 527.22 31.08 -12.45 6,003,824.23 388,000.96 1.35 31.82 MWD+IFR-AK-CAZ-SC(2) 672.55 8.77 7.13 670.15 619.83 43.90 -12.21 6,003,837.04 388,001.40 2.66 41.47 MWD+IFR-AK-CAZ-SC(2) 765.63 11.04 12.22 761.84 711.52 59.65 -9.44 6,003,852.75 388,004.41 2.61 51.76 MWD+IFR-AK-CAZ-SC(2) 858.85 14.25 10.37 852.78 802.46 79.67 -5.48 6,003,872.70 388,008.66 3.47 64.55 MWD+IFR-AK-CAZ-SC(2) 4/23/2012 11:38:10AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips b-' Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod 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 950.61 19.05 10.88 940.67 890.35 105.50 -0.62 6,003,898.45 388,013.91 5.23 81.21 MWD+IFR-AK-CAZ-SC(2) 1,046.30 22.70 9.98 1,030.07 979.75 139.03 5.53 6,003,931.89 388,020.56 3.83 102.95 MWD+IFR-AK-CAZ-SC(2) 1,139.52 23.21 9.34 1,115.90 1,065.58 174.87 11.63 6,003,967.63 388,027.20 0.61 126.48 MWD+IFR-AK-CAZ-SC(2) 1,233.55 24.07 7.50 1,202.04 1,151.72 212.16 17.14 6,004,004.83 388,033.27 1.20 151.51 MWD+IFR-AK-CAZ-SC(2) 1,327.20 26.02 5.77 1,286.88 1,236.56 251.54 21.70 6,004,044.13 388,038.41 2.22 178.75 MWD+IFR-AK-CAZ-SC(2) 1,420.62 30.47 6.38 1,369.16 1,318.84 295.49 26.39 6,004,088.00 388,043.77 4.77 209.39 MWD+IFR-AK-CAZ-SC(2) 1,513.13 35.30 4.68 1,446.83 1,396.51 345.47 31.18 6,004,137.90 388,049.31 5.32 244.60 MWD+IFR-AK-CAZ-SC(2) 1,608.06 40.40 6.01 1,521.76 1,471.44 403.44 36.64 6,004,195.78 388,055.64 5.44 285.50 MWD+IFR-AK-CAZ-SC(2) 1,703.87 44.97 8.04 1,592.17 1,541.85 467.88 44.63 6,004,260.08 388,064.59 4.98 329.73 MWD+IFR-AK-CAZ-SC(2) 1,797.28 48.95 10.26 1,655.92 1,605.60 535.25 55.53 6,004,327.28 388,076.50 4.60 374.33 MWD+IFR-AK-CAZ-SC(2) 1,891.94 52.19 12.28 1,716.04 1,665.72 606.94 69.84 6,004,398.74 388,091.88 3.80 420.04 MWD+IFR-AK-CAZ-SC(2) 1,985.64 53.40 14.99 1,772.70 1,722.38 679.45 87.45 6,004,470.97 388,110.57 2.64 464.28 MWD+IFR-AK-CAZ-SC(2) 2,081.01 53.52 20.62 1,829.51 1,779.19 752.35 110.86 6,004,543.50 388,135.08 4.74 505.07 MWD+IFR-AK-CAZ-SC(2) 2,174.34 54.90 20.63 1,884.09 1,833.77 823.20 137.53 6,004,613.94 388,162.80 1.48 542.20 MWD+IFR-AK-CAZ-SC(2) 2,270.36 59.16 21.90 1,936.33 1,886.01 898.24 166.76 6,004,688.53 388,193.15 4.57 580.90 MWD+IFR-AK-CAZ-SC(2) 2,363.88 62.95 21.73 1,981.59 1,931.27 974.21 197.16 6,004,764.03 388,224.69 4.06 619.55 MWD+IFR-AK-CAZ-SC(2) 2,455.83 65.78 24.17 2,021.37 1,971.05 1,050.52 229.50 6,004,839.84 388,258.16 3.90 657.23 MWD+IFR-AK-CAZ-SC(2) 2,549.60 66.13 23.20 2,059.58 2,009.26 1,128.94 263.90 6,004,917.73 388,293.73 1.02 695.19 MWD+IFR-AK-CAZ-SC(2) 2,643.70 66.96 24.94 2,097.03 2,046.71 1,207.75 299.11 6,004,996.00 388,330.12 1.91 732.93 MWD+IFR-AK-CAZ-SC(2) 2,739.27 67.90 24.02 2,133.71 2,083.39 1,288.07 335.67 6,005,075.75 388,367.88 1.33 770.95 MWD+IFR-AK-CAZ-SC(2) 2,834.26 68.24 24.85 2,169.19 2,118.87 1,368.29 372.13 6,005,155.41 388,405.53 0.89 808.98 MWD+IFR-AK-CAZ-SC(2) 2,927.75 68.17 25.19 2,203.90 2,153.58 1,446.95 408.84 6,005,233.50 388,443.41 0.35 845.63 MWD+IFR-AK-CAZ-SC(2) 3,023.05 67.51 25.16 2,239.85 2,189.53 1,526.83 446.38 6,005,312.80 388,482.15 0.69 882.69 MWD+IFR-AK-CAZ-SC(2) 3,118.96 67.67 24.59 2,276.41 2,226.09 1,607.27 483.68 6,005,392.67 388,520.64 0.57 920.34 MWD+IFR-AK-CAZ-SC(2) 3,210.56 67.05 27.24 2,311.68 2,261.36 1,683.30 520.62 6,005,468.13 388,558.72 2.75 954.84 MWD+IFR-AK-CAZ-SC(2) 3,305.03 66.56 30.37 2,348.89 2,298.57 1,759.38 562.45 6,005,543.57 388,601.68 3.09 986.23 MWD+IFR-AK-CAZ-SC(2) 3,398.79 67.95 30.65 2,385.14 2,334.82 1,833.88 606.35 6,005,617.39 388,646.68 1.51 1,015.08 MWD+IFR-AK-CAZ-SC(2) 3,494.41 66.38 29.92 2,422.25 2,371.93 1,909.97 650.79 6,005,692.80 388,692.26 1.79 1,044.80 MWD+IFR-AK-CAZ-SC(2) 3,589.41 66.92 30.57 2,459.90 2,409.58 1,985.32 694.72 6,005,767.47 388,737.31 0.85 1,074.28 MWD+IFR-AK-CAZ-SC(2) 3,650.35 67.11 30.52 2,483.70 2,433.38 2,033.63 723.23 6,005,815.35 388,766.54 0.32 1,092.97 MWD+IFR-AK-CAZ-SC(3) 10-3/4"x 13-1/2" 3,685.10 67.22 30.49 2,497.19 2,446.87 2,061.23 739.49 6,005,842.70 388,783.21 0.32 1,103.66 MWD+IFR-AK-CAZ-SC(3) 3,783.45 63.96 31.81 2,537.83 2,487.51 2,137.87 785.80 6,005,918.63 388,830.66 3.53 1,132.60 MWD+IFR-AK-CAZ-SC(3) 3,881.02 63.26 31.09 2,581.19 2,530.87 2,212.43 831.40 6,005,992.49 388,877.37 0.98 1,160.40 MWD+IFR-AK-CAZ-SC(3) 3,979.75 64.45 31.04 2,624.70 2,574.38 2,288.34 877.13 6,006,067.70 388,924.24 1.21 1,189.16 MWD+IFR-AK-CAZ-SC(3) 4,078.56 66.03 31.35 2,666.08 2,615.76 2,365.09 923.61 6,006,143.74 388,971.85 1.62 1,218.08 MWD+IFR-AK-CAZ-SC(3) 4,172.89 66.34 30.62 2,704.17 2,653.85 2,439.08 968.03 6,006,217.04 389,017.38 0.78 1,246.20 MWD+IFR-AK-CAZ-SC(3) 4,267.23 66.39 30.06 2,741.99 2,691.67 2,513.67 1,011.69 6,006,290.96 389,062.14 0.55 1,275.28 MWD+IFR-AK-CAZ-SC(3) 4,361.96 66.72 30.22 2,779.68 2,729.36 2,588.83 1,055.33 6,006,365.45 389,106.90 0.38 1,304.80 MWD+IFR-AK-CAZ-SC(3) 4,455.01 66.69 29.58 2,816.48 2,766.16 2,662.91 1,097.93 6,006,438.89 389,150.61 0.63 1,334.17 MWD+IFR-AK-CAZ-SC(3) 4/23/2012 11:38:10AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips ti' Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,548.88 66.50 30.02 2,853.77 2,803.45 2,737.67 1,140.74 6,006,512.98 389,194.53 0.48 1,363.92 MWD+IFR-AK-CAZ-SC(3) 4,641.40 66.37 30.72 2,890.76 2,840.44 2,810.84 1,183.62 6,006,585.49 389,238.50 0.71 1,392.41 MWD+IFR-AK-CAZ-SC(3) 4,735.52 66.55 30.87 2,928.35 2,878.03 2,884.96 1,227.80 6,006,658.94 389,283.78 0.24 1,420.79 MWD+IFR-AK-CAZ-SC(3) 4,829.71 66.86 30.06 2,965.60 2,915.28 2,959.52 1,271.66 6,006,732.83 389,328.75 0.86 1,449.72 MWD+IFR-AK-CAZ-SC(3) 4,922.03 66.79 31.25 3,001.93 2,951.61 3,032.53 1,314.93 6,006,805.18 389,373.11 1.19 1,477.84 MWD+IFR-AK-CAZ-SC(3) 5,016.60 66.68 32.18 3,039.28 2,988.96 3,106.44 1,360.60 6,006,878.38 389,419.88 0.91 1,505.09 MWD+IFR-AK-CAZ-SC(3) 5,111.16 66.73 31.86 3,076.68 3,026.36 3,180.08 1,406.65 6,006,951.31 389,467.02 0.32 1,531.90 MWD+IFR-AK-CAZ-SC(3) 5,205.74 66.84 33.75 3,113.96 3,063.64 3,253.13 1,453.74 6,007,023.65 389,515.20 1.84 1,557.60 MWD+IFR-AK-CAZ-SC(3) 5,299.24 66.82 32.73 3,150.75 3,100.43 3,325.02 1,500.86 6,007,094.82 389,563.39 1.00 1,582.38 MWD+IFR-AK-CAZ-SC(3) 5,393.71 66.81 32.48 3,187.95 3,137.63 3,398.18 1,547.65 6,007,167.26 389,611.27 0.24 1,608.35 MWD+IFR-AK-CAZ-SC(3) 5,488.10 66.80 33.66 3,225.12 3,174.80 3,470.88 1,594.99 6,007,239.24 389,659.69 1.15 1,633.61 MWD+IFR-AK-CAZ-SC(3) 5,582.97 66.90 33.76 3,262.42 3,212.10 3,543.45 1,643.40 6,007,311.06 389,709.18 0.14 1,658.08 MWD+IFR-AK-CAZ-SC(3) 5,677.32 66.78 33.43 3,299.53 3,249.21 3,615.70 1,691.40 6,007,382.58 389,758.25 0.35 1,682.58 MWD+IFR-AK-CAZ-SC(3) 5,771.98 66.88 32.31 3,336.78 3,286.46 3,688.80 1,738.63 6,007,454.95 389,806.57 1.09 1,708.21 MWD+IFR-AK-CAZ-SC(3) 5,864.94 66.82 32.02 3,373.32 3,323.00 3,761.15 1,784.14 6,007,526.61 389,853.15 0.29 1,734.39 MWD+IFR-AK-CAZ-SC(3) 5,961.24 66.67 31.81 3,411.34 3,361.02 3,836.25 1,830.91 6,007,601.00 389,901.04 0.25 1,761.85 MWD+IFR-AK-CAZ-SC(3) 6,053.27 66.85 32.06 3,447.66 3,397.34 3,908.02 1,875.64 6,007,672.07 389,946.84 0.32 1,788.08 MWD+IFR-AK-CAZ-SC(3) 6,150.92 66.60 32.69 3,486.24 3,435.92 3,983.78 1,923.67 6,007,747.10 389,996.00 0.65 1,815.24 MWD+IFR-AK-CAZ-SC(3) 6,244.12 66.84 32.33 3,523.08 3,472.76 4,055.97 1,969.68 6,007,818.59 390,043.08 0.44 1,840.97 MWD+IFR-AK-CAZ-SC(3) 6,335.09 66.84 31.38 3,558.86 3,508.54 4,127.01 2,013.82 6,007,888.95 390,088.28 0.96 1,867.01 MWD+IFR-AK-CAZ-SC(3) 6,431.97 66.85 30.37 3,596.95 3,546.63 4,203.46 2,059.53 6,007,964.71 390,135.13 0.96 1,896.20 MWD+IFR-AK-CAZ-SC(3) 6,524.44 66.57 30.18 3,633.51 3,583.19 4,276.82 2,102.35 6,008,037.40 390,179.04 0.36 1,924.86 MWD+IFR-AK-CAZ-SC(3) 6,620.01 66.94 29.97 3,671.23 3,620.91 4,352.81 2,146.36 6,008,112.71 390,224.18 0.44 1,954.79 MWD+IFR-AK-CAZ-SC(3) 6,714.17 66.56 30.45 3,708.40 3,658.08 4,427.57 2,189.89 6,008,186.81 390,268.82 0.62 1,984.08 MWD+IFR-AK-CAZ-SC(3) 6,808.78 66.61 30.72 3,746.00 3,695.68 4,502.31 2,234.07 6,008,260.87 390,314.11 0.27 2,012.94 MWD+IFR-AK-CAZ-SC(3) 6,903.53 66.93 31.15 3,783.37 3,733.05 4,576.99 2,278.82 6,008,334.87 390,359.98 0.54 2,041.38 MWD+IFR-AK-CAZ-SC(3) 6,997.47 66.54 31.03 3,820.48 3,770.16 4,650.90 2,323.39 6,008,408.09 390,405.64 0.43 2,069.35 MWD+IFR-AK-CAZ-SC(3) 7,092.23 66.49 31.77 3,858.24 3,807.92 4,725.08 2,368.67 6,008,481.58 390,452.03 0.72 2,097.07 MWD+IFR-AK-CAZ-SC(3) 7,186.87 66.49 31.97 3,895.99 3,845.67 4,798.78 2,414.49 6,008,554.58 390,498.94 0.19 2,124.07 MWD+IFR-AK-CAZ-SC(3) 7,281.35 66.96 32.07 3,933.32 3,883.00 4,872.37 2,460.51 6,008,627.46 390,546.06 0.51 2,150.86 MWD+IFR-AK-CAZ-SC(3) 7,375.80 67.19 32.02 3,970.12 3,919.80 4,946.10 2,506.66 6,008,700.49 390,593.31 0.25 2,177.68 MWD+IFR-AK-CAZ-SC(3) 7,470.30 66.78 32.16 4,007.06 3,956.74 5,019.79 2,552.87 6,008,773.47 390,640.61 0.45 2,204.43 MWD+IFR-AK-CAZ-SC(3) 7,562.09 66.24 31.24 4,043.65 3,993.33 5,091.41 2,597.11 6,008,844.41 390,685.91 1.09 2,230.86 MWD+IFR-AK-CAZ-SC(3) 7,658.71 66.65 30.96 4,082.26 4,031.94 5,167.25 2,642.86 6,008,919.55 390,732.79 0.50 2,259.55 MWD+IFR-AK-CAZ-SC(3) r �v.A, 7,748.59 67.06 31.61 4,117.59 4,067.27 5,237.88 2,685.77 6,008,989.52 390,776.76 0.81 2,286.07 MWD+IFR-AK-CAZ-SC(3) 7,845.84 66.90 30.98 4,155.62 4,105.30 5,314.36 2,732.27 6,009,065.29 390,824.39 0.62 2,314.77 MWD+IFR-AK-CAZ-SC(3) e +v 7,931.39 66.45 31.41 4,189.49 4,139.17 5,381.56 2,772.96 6,009,131.87 390,866.08 0.70 2,340.09 MWD+IFR-AK-CAZ-SC(3) 8,033.54 66.54 31.30 4,230.23 4,179.91 5,461.55 2,821.70 6,009,211.11 390,916.01 0.13 2,370.04 MWD+IFR-AK-CAZ-SC(3) 8,125.03 66.59 31.38 4,266.62 4,216.30 5,533.25 2,865.36 6,009,282.14 390,960.74 0.10 2,396.90 MWD+IFR-AK-CAZ-SC(3) 8,221.10 66.70 32.39 4,304.71 4,254.39 5,608.14 2,911.95 6,009,356.32 391,008.44 0.97 2,424.32 MWD+IFR-AK-CAZ-SC(3) 4/23/2012 11:38:10AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1oo) (ft) Survey Tool Name 8,313.51 66.83 32.86 4,341.16 4,290.84 5,679.66 2,957.73 6,009,427.13 391,055.29 0.49 2,449.68 MWD+IFR-AK-CAZ-SC(3) 8,408.43 66.79 32.18 4,378.54 4,328.22 5,753.23 3,004.63 6,009,499.98 391,103.29 0.66 2,475.89 MWD+IFR-AK-CAZ-SC(3) 8,502.85 66.72 31.13 4,415.80 4,365.48 5,827.07 3,050.16 6,009,573.13 391,149.91 1.02 2,503.19 MWD+IFR-AK-CAZ-SC(3) 8,597.15 66.88 30.84 4,452.95 4,402.63 5,901.38 3,094.78 6,009,646.75 391,195.64 0.33 2,531.43 MWD+IFR-AK-CAZ-SC(3) 8,690.27 66.81 31.34 4,489.57 4,439.25 5,974.70 3,138.99 6,009,719.40 391,240.94 0.50 2,559.18 MWD+IFR-AK-CAZ-SC(3) 8,786.38 66.64 31.59 4,527.55 4,477.23 6,050.00 3,185.08 6,009,794.00 391,288.15 0.30 2,587.24 MWD+IFR-AK-CAZ-SC(3) 8,880.97 66.52 31.17 4,565.14 4,514.82 6,124.11 3,230.27 6,009,867.40 391,334.45 0.43 2,614.96 MWD+IFR-AK-CAZ-SC(3) 8,975.33 66.86 32.30 4,602.48 4,552.16 6,197.81 3,275.86 6,009,940.41 391,381.12 1.16 2,642.12 MWD+IFR-AK-CAZ-SC(3) 9,070.86 66.88 31.67 4,640.01 4,589.69 6,272.32 3,322.39 6,010,014.21 391,428.77 0.61 2,669.28 MWD+IFR-AK-CAZ-SC(3) 9,164.39 67.46 31.09 4,676.30 4,625.98 6,345.91 3,367.28 6,010,087.11 391,474.75 0.84 2,696.81 MWD+IFR-AK-CAZ-SC(3) 9,255.88 67.21 29.92 4,711.56 4,661.24 6,418.65 3,410.13 6,010,159.19 391,518.69 1.21 2,724.98 MWD+IFR-AK-CAZ-SC(3) 9,350.25 66.96 29.94 4,748.30 4,697.98 6,493.98 3,453.50 6,010,233.86 391,563.18 0.27 2,754.81 MWD+IFR-AK-CAZ-SC(3) 9,445.28 67.17 30.30 4,785.33 4,735.01 6,569.68 3,497.42 6,010,308.88 391,608.22 0.41 2,784.57 MWD+IFR-AK-CAZ-SC(3) 9,540.15 67.36 29.77 4,822.00 4,771.68 6,645.43 3,541.21 6,010,383.96 391,653.14 0.55 2,814.45 MWD+IFR-AK-CAZ-SC(3) 9,633.97 66.92 29.13 4,858.44 4,808.12 6,720.71 3,583.72 6,010,458.59 391,696.77 0.78 2,844.79 MWD+IFR-AK-CAZ-SC(3) 9,728.48 66.71 28.91 4,895.65 4,845.33 6,796.68 3,625.86 6,010,533.91 391,740.05 0.31 2,875.90 MWD+IFR-AK-CAZ-SC(3) 9,823.12 66.52 29.08 4,933.22 4,882.90 6,872.66 3,667.97 6,010,609.24 391,783.28 0.26 2,907.04 MWD+IFR-AK-CAZ-SC(3) 9,916.14 66.30 29.37 4,970.44 4,920.12 6,947.05 3,709.59 6,010,683.00 391,826.01 0.37 2,937.27 MWD+IFR-AK-CAZ-SC(3) 10,008.82 66.53 29.54 5,007.52 4,957.20 7,021.01 3,751.36 6,010,756.32 391,868.88 0.30 2,967.08 MWD+IFR-AK-CAZ-SC(3) 10,102.48 66.78 29.82 5,044.64 4,994.32 7,095.72 3,793.94 6,010,830.37 391,912.57 0.38 2,996.94 MWD+IFR-AK-CAZ-SC(3) 10,197.24 67.04 29.12 5,081.80 5,031.48 7,171.61 3,836.82 6,010,905.60 391,956.59 0.73 3,027.51 MWD+IFR-AK-CAZ-SC(3) 10,291.41 66.76 30.29 5,118.75 5,068.43 7,246.85 3,879.74 6,010,980.18 392,000.63 1.18 3,057.56 MWD+IFR-AK-CAZ-SC(3) 10,382.46 67.04 29.84 5,154.47 5,104.15 7,319.33 3,921.70 6,011,052.02 392,043.66 0.55 3,086.11 MWD+IFR-AK-CAZ-SC(3) 10,478.55 66.62 30.37 5,192.28 5,141.96 7,395.75 3,966.01 6,011,127.76 392,089.11 0.67 3,116.17 MWD+IFR-AK-CAZ-SC(3) 10,571.83 66.41 29.74 5,229.45 5,179.13 7,469.80 4,008.86 6,011,201.15 392,133.06 0.66 3,145.36 MWD+IFR-AK-CAZ-SC(3) 10,666.11 66.21 30.47 5,267.33 5,217.01 7,544.49 4,052.16 6,011,275.18 392,177.47 0.74 3,174.74 MWD+IFR-AK-CAZ-SC(3) 10,760.21 66.50 31.09 5,305.07 5,254.75 7,618.55 4,096.27 6,011,348.56 392,222.69 0.68 3,203.11 MWD+IFR-AK-CAZ-SC(3) 10,854.99 66.73 31.60 5,342.69 5,292.37 7,692.84 4,141.53 6,011,422.16 392,269.05 0.55 3,230.94 MWD+IFR-AK-CAZ-SC(3) 10,949.68 66.71 30.74 5,380.12 5,329.80 7,767.27 4,186.54 6,011,495.90 392,315.18 0.83 3,259.01 MWD+IFR-AK-CAZ-SC(3) 11,043.26 66.92 31.84 5,416.96 5,366.64 7,840.78 4,231.22 6,011,568.72 392,360.95 1.10 3,286.61 MWD+IFR-AK-CAZ-SC(3) 11,137.60 66.98 31.75 5,453.90 5,403.58 7,914.56 4,276.96 6,011,641.80 392,407.78 0.11 3,313.73 MWD+IFR-AK-CAZ-SC(3) 11,232.62 66.92 31.44 5,491.10 5,440.78 7,989.03 4,322.77 6,011,715.57 392,454.70 0.31 3,341.33 MWD+IFR-AK-CAZ-SC(3) 11,327.27 67.09 32.10 5,528.08 5,477.76 8,063.11 4,368.64 6,011,788.94 392,501.67 0.67 3,368.59 MWD+IFR-AK-CAZ-SC(3) 11,420.59 66.56 31.36 5,564.80 5,514.48 8,136.07 4,413.76 6,011,861.22 392,547.88 0.92 3,395.48 MWD+IFR-AK-CAZ-SC(3) 11,514.71 66.73 31.91 5,602.12 5,551.80 8,209.64 4,459.08 6,011,934.09 392,594.29 0.57 3,422.71 MWD+IFR-AK-CAZ-SC(3) 11,609.37 67.01 32.25 5,639.30 5,588.98 8,283.40 4,505.31 6,012,007.14 392,641.62 0.44 3,449.49 MWD+IFR-AK-CAZ-SC(3) 11,704.40 67.04 32.00 5,676.39 5,626.07 8,357.49 4,551.84 6,012,080.53 392,689.25 0.24 3,476.35 MWD+IFR-AK-CAZ-SC(3) 11,798.38 67.46 32.16 5,712.74 5,662.42 8,430.93 4,597.87 6,012,153.25 392,736.37 0.47 3,503.01 MWD+IFR-AK-CAZ-SC(3) 11,892.01 67.14 31.79 5,748.87 5,698.55 8,504.20 4,643.61 6,012,225.83 392,783.21 0.50 3,529.74 MWD+IFR-AK-CAZ-SC(3) 11,986.79 66.57 30.75 5,786.12 5,735.80 8,578.69 4,688.85 6,012,299.62 392,829.55 1.17 3,557.72 MWD+IFR-AK-CAZ-SC(3) 4/23/2012 11:38:10AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,081.00 66.12 30.67 5,823.92 5,773.60 8,652.88 4,732.92 6,012,373.14 392,874.73 0.48 3,586.23 MWD+IFR-AK-CAZ-SC(3) 12,172.37 65.95 30.51 5,861.04 5,810.72 8,724.75 4,775.41 6,012,444.36 392,918.28 0.25 3,613.98 MWD+IFR-AK-CAZ-SC(3) 12,267.65 66.05 30.82 5,899.79 5,849.47 8,799.62 4,819.80 6,012,518.55 392,963.79 0.32 3,642.80 MWD+IFR-AK-CAZ-SC(3) 12,361.75 66.11 30.52 5,937.94 5,887.62 8,873.61 4,863.68 6,012,591.86 393,008.77 0.30 3,671.27 MWD+IFR-AK-CAZ-SC(3) 12,456.56 66.28 27.63 5,976.22 5,925.90 8,949.41 4,905.82 6,012,667.02 393,052.05 2.79 3,702.24 MWD+IFR-AK-CAZ-SC(3) 12,551.04 67.07 24.92 6,013.63 5,963.31 9,027.20 4,944.22 6,012,744.21 393,091.60 2.76 3,737.15 MWD+IFR-AK-CAZ-SC(3) 12,645.18 67.43 21.97 6,050.04 5,999.72 9,106.84 4,978.75 6,012,823.32 393,127.32 2.91 3,775.96 MWD+IFR-AK-CAZ-SC(3) 12,736.99 67.52 18.11 6,085.23 6,034.91 9,186.49 5,007.81 6,012,902.52 393,157.56 3.88 3,818.30 MWD+IFR-AK-CAZ-SC(3) 12,829.22 67.94 16.26 6,120.18 6,069.86 9,268.03 5,033.02 6,012,983.66 393,184.00 1.91 3,864.56 MWD+IFR-AK-CAZ-SC(3) 12,925.88 68.14 12.84 6,156.34 6,106.02 9,354.78 5,055.54 6,013,070.06 393,207.81 3.29 3,916.54 MWD+IFR-AK-CAZ-SC(3) 13,017.03 68.03 10.55 6,190.36 6,140.04 9,437.58 5,072.68 6,013,152.59 393,226.19 2.33 3,968.95 MWD+IFR-AK-CAZ-SC(3) 13,112.66 68.49 8.71 6,225.78 6,175.46 9,525.15 5,087.53 6,013,239.92 393,242.35 1.85 4,026.49 MWD+IFR-AK-CAZ-SC(3) 13,210.88 68.45 8.19 6,261.83 6,211.51 9,615.53 5,100.96 6,013,330.07 393,257.13 0.49 4,087.09 MWD+IFR-AK-CAZ-SC(3) 13,304.72 69.08 5.81 6,295.82 6,245.50 9,702.34 5,111.61 6,013,416.71 393,269.09 2.46 4,146.74 MWD+IFR-AK-CAZ-SC(3) 13,398.62 69.93 4.82 6,328.70 6,278.38 9,789.91 5,119.76 6,013,504.14 393,278.55 1.34 4,208.59 MWD+IFR-AK-CAZ-SC(3) 13,493.64 70.85 4.05 6,360.59 6,310.27 9,879.15 5,126.68 6,013,593.26 393,286.80 1.23 4,272.50 MWD+IFR-AK-CAZ-SC(3) 13,587.57 71.31 2.07 6,391.05 6,340.73 9,967.88 5,131.42 6,013,681.90 393,292.87 2.05 4,337.42 MWD+IFR-AK-CAZ-SC(3) 13,683.50 71.52 359.69 6,421.63 6,371.31 10,058.79 5,132.82 6,013,772.76 393,295.63 2.36 4,406.17 MWD+IFR-AK-CAZ-SC(3) 13,778.31 72.26 356.90 6,451.10 6,400.78 10,148.85 5,130.13 6,013,862.85 393,294.30 2.90 4,476.88 MWD+IFR-AK-CAZ-SC(3) 13,872.53 73.28 354.92 6,479.01 6,428.69 10,238.60 5,123.71 6,013,952.68 393,289.22 2.28 4,549.77 MWD+IFR-AK-CAZ-SC(3) 13,964.92 74.08 352.23 6,504.98 6,454.66 10,326.70 5,113.78 6,014,040.91 393,280.62 2.93 4,623.64 MWD+IFR-AK-CAZ-SC(3) 14,062.33 74.73 349.37 6,531.17 6,480.85 10,419.31 5,098.78 6,014,133.73 393,267.01 2.91 4,704.22 MWD+IFR-AK-CAZ-SC(3) 14,154.66 75.21 346.89 6,555.12 6,504.80 10,506.56 5,080.44 6,014,221.24 393,249.98 2.65 4,782.85 MWD+IFR-AK-CAZ-SC(3) 14,251.99 75.72 344.89 6,579.55 6,529.23 10,597.93 5,057.47 6,014,312.93 393,228.39 2.06 4,867.61 MWD+IFR-AK-CAZ-SC(3) 14,345.22 76.67 342.42 6,601.80 6,551.48 10,684.80 5,031.99 6,014,400.17 393,204.22 2.77 4,950.53 MWD+IFR-AK-CAZ-SC(3) 14,435.95 77.76 338.69 6,621.88 6,571.56 10,768.21 5,002.53 6,014,484.01 393,176.02 4.19 5,033.36 MWD+IFR-AK-CAZ-SC(3) 14,526.66 78.67 337.25 6,640.41 6,590.09 10,850.52 4,969.23 6,014,566.80 393,143.95 1.85 5,117.83 MWD+IFR-AK-CAZ-SC(3) 14,620.32 79.39 335.17 6,658.23 6,607.91 10,934.65 4,932.14 6,014,651.47 393,108.13 2.31 5,206.11 MWD+IFR-AK-CAZ-SC(3) 14,709.53 80.42 333.04 6,673.87 6,623.55 11,013.66 4,893.78 6,014,731.03 393,070.97 2.62 5,291.29 MWD+IFR-AK-CAZ-SC(3) 14,804.27 81.15 329.86 6,689.05 6,638.73 11,095.79 4,849.09 6,014,813.82 393,027.52 3.40 5,382.93 MWD+IFR-AK-CAZ-SC(3) 14,898.50 81.47 326.86 6,703.29 6,652.97 11,175.08 4,800.23 6,014,893.83 392,979.86 3.17 5,475.08 MWD+IFR-AK-CAZ-SC(3) 14,993.51 81.87 324.04 6,717.06 6,666.74 11,252.50 4,746.92 6,014,972.03 392,927.72 2.97 5,568.65 MWD+IFR-AK-CAZ-SC(3) 15,087.85 81.81 324.11 6,730.45 6,680.13 11,328.12 4,692.13 6,015,048.46 392,874.07 0.10 5,661.80 MWD+IFR-AK-CAZ-SC(3) 15,182.46 80.80 324.10 6,744.75 6,694.43 11,403.88 4,637.30 6,015,125.03 392,820.39 1.07 5,755.08 MWD+IFR-AK-CAZ-SC(3) 15,196.15 81.49 324.05 6,746.86 6,696.54 11,414.84 4,629.36 6,015,136.10 392,812.62 5.05 5,768.58 MWD+IFR-AK-CAZ-SC(3) 15,242.69 82.36 324.50 6,753.39 6,703.07 11,452.24 4,602.46 6,015,173.90 392,786.28 2.11 5,814.53 MWD+IFR-AK-CAZ-SC(4) 7-5/8"X 9-7/8" 15,286.17 83.18 324.92 6,758.86 6,708.54 11,487.45 4,577.54 6,015,209.48 392,761.90 2.11 5,857.51 MWD+IFR-AK-CAZ-SC(4) 15,327.77 84.11 325.34 6,763.47 6,713.15 11,521.37 4,553.90 6,015,243.75 392,738.77 2.45 5,898.69 MWD+IFR-AK-CAZ-SC(4) 15,426.64 86.28 327.74 6,771.75 6,721.43 11,603.56 4,499.59 6,015,326.73 392,685.70 3.27 5,996.56 MWD+IFR-AK-CAZ-SC(4) 15,523.22 89.26 328.83 6,775.51 6,725.19 11,685.64 4,448.86 6,015,409.56 392,636.22 3.29 6,092.05 MWD+IFR-AK-CAZ-SC(4) 4/23/2012 11:38:10AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,619.04 90.84 327.57 6,775.42 6,725.10 11,767.08 4,398.37 6,015,491.73 392,586.96 2.11 6,186.88 MWD+IFR-AK-CAZ-SC(4) 15,714.49 91.89 326.61 6,773.15 6,722.83 11,847.18 4,346.53 6,015,572.60 392,536.33 1.49 6,281.57 MWD+IFR-AK-CAZ-SC(4) 15,809.19 92.12 324.43 6,769.84 6,719.52 11,925.20 4,292.96 6,015,651.40 392,483.94 2.31 6,375.77 MWD+IFR-AK-CAZ-SC(4) 15,904.81 91.68 323.85 6,766.67 6,716.35 12,002.65 4,236.97 6,015,729.68 392,429.12 0.76 6,471.09 MWD+IFR-AK-CAZ-SC(4) 16,000.26 92.38 324.12 6,763.29 6,712.97 12,079.81 4,180.88 6,015,807.66 392,374.20 0.79 6,566.25 MWD+IFR-AK-CAZ-SC(4) 16,095.52 90.82 321.51 6,760.62 6,710.30 12,155.66 4,123.34 6,015,884.37 392,317.81 3.19 6,661.34 MWD+IFR-AK-CAZ-SC(4) 16,190.20 90.07 320.26 6,759.89 6,709.57 12,229.11 4,063.61 6,015,958.70 392,259.19 1.54 6,756.01 MWD+IFR-AK-CAZ-SC(4) 16,285.70 90.64 318.02 6,759.30 6,708.98 12,301.34 4,001.14 6,016,031.85 392,197.82 2.42 6,851.49 MWD+IFR-AK-CAZ-SC(4) 16,381.57 89.44 316.71 6,759.23 6,708.91 12,371.86 3,936.20 6,016,103.33 392,133.96 1.85 6,947.25 MWD+IFR-AK-CAZ-SC(4) 16,477.38 88.96 318.79 6,760.57 6,710.25 12,442.77 3,871.79 6,016,175.20 392,070.62 2.23 7,042.98 MWD+IFR-AK-CAZ-SC(4) 16,572.98 89.85 321.62 6,761.56 6,711.24 12,516.21 3,810.62 6,016,249.54 392,010.56 3.10 7,138.56 MWD+IFR-AK-CAZ-SC(4) 16,668.07 89.71 323.48 6,761.93 6,711.61 12,591.70 3,752.80 6,016,325.88 391,953.88 1.96 7,233.55 MWD+IFR-AK-CAZ-SC(4) 16,762.81 89.90 325.33 6,762.25 6,711.93 12,668.73 3,697.66 6,016,403.72 391,899.91 1.96 7,328.01 MWD+IFR-AK-CAZ-SC(4) 16,859.24 90.40 324.70 6,762.00 6,711.68 12,747.74 3,642.37 6,016,483.54 391,845.82 0.83 7,424.06 MWD+IFR-AK-CAZ-SC(4) 16,954.79 90.83 324.59 6,760.97 6,710.65 12,825.66 3,587.08 6,016,562.28 391,791.71 0.46 7,519.30 MWD+IFR-AK-CAZ-SC(4) 17,049.39 91.70 325.03 6,758.88 6,708.56 12,902.95 3,532.58 6,016,640.37 391,738.38 1.03 7,613.54 MWD+IFR-AK-CAZ-SC(4) 17,145.93 92.25 324.87 6,755.56 6,705.24 12,981.94 3,477.17 6,016,720.18 391,684.16 0.59 7,709.66 MWD+IFR-AK-CAZ-SC(4) 17,240.93 91.17 323.92 6,752.72 6,702.40 13,059.14 3,421.89 6,016,798.19 391,630.05 1.51 7,804.34 MWD+IFR-AK-CAZ-SC(4) 17,336.75 91.94 324.32 6,750.12 6,699.80 13,136.75 3,365.75 6,016,876.63 391,575.09 0.91 7,899.87 MWD+IFR-AK-CAZ-SC(4) 17,432.47 91.12 323.86 6,747.56 6,697.24 13,214.25 3,309.63 6,016,954.95 391,520.14 0.98 7,995.31 MWD+IFR-AK-CAZ-SC(4) 17,527.95 92.57 325.03 6,744.49 6,694.17 13,291.88 3,254.14 6,017,033.40 391,465.83 1.95 8,090.45 MWD+IFR-AK-CAZ-SC(4) 17,622.86 92.68 323.91 6,740.14 6,689.82 13,369.04 3,199.04 6,017,111.37 391,411.90 1.18 8,184.97 MWD+IFR-AK-CAZ-SC(4) 17,718.04 91.42 322.92 6,736.74 6,686.42 13,445.42 3,142.35 6,017,188.58 391,356.37 1.68 8,279.92 MWD+IFR-AK-CAZ-SC(4) 17,814.91 91.25 322.42 6,734.48 6,684.16 13,522.42 3,083.63 6,017,266.45 391,298.81 0.55 8,376.66 MWD+IFR-AK-CAZ-SC(4) 17,906.97 90.56 322.36 6,733.03 6,682.71 13,595.34 3,027.45 6,017,340.20 391,243.74 0.75 8,468.63 MWD+IFR-AK-CAZ-SC(4) 18,005.47 91.76 321.17 6,731.03 6,680.71 13,672.69 2,966.51 6,017,418.45 391,183.96 1.72 8,567.06 MWD+IFR-AK-CAZ-SC(4) 18,100.52 88.93 321.45 6,730.46 6,680.14 13,746.87 2,907.10 6,017,493.51 391,125.68 2.99 8,662.07 MWD+IFR-AK-CAZ-SC(4) 18,196.15 88.03 322.57 6,733.00 6,682.68 13,822.21 2,848.26 6,017,569.72 391,067.98 1.50 8,757.60 MWD+IFR-AK-CAZ-SC(4) 18,291.32 87.92 324.16 6,736.36 6,686.04 13,898.53 2,791.51 6,017,646.87 391,012.38 1.67 8,852.55 MWD+IFR-AK-CAZ-SC(4) 18,384.49 86.72 325.27 6,740.72 6,690.40 13,974.50 2,737.75 6,017,723.63 390,959.78 1.75 8,945.30 MWD+IFR-AK-CAZ-SC(4) 18,481.22 90.76 332.51 6,742.85 6,692.53 14,057.23 2,687.83 6,017,807.09 390,911.11 8.57 9,040.76 MWD+IFR-AK-CAZ-SC(4) 18,532.49 87.52 333.38 6,743.62 6,693.30 14,102.88 2,664.51 6,017,853.08 390,888.48 6.54 9,090.71 MWD+IFR-AK-CAZ-SC(4) 18,577.94 86.27 332.00 6,746.08 6,695.76 14,143.20 2,643.69 6,017,893.71 390,868.27 4.09 9,134.99 MWD+IFR-AK-CAZ-SC(4) 18,671.28 87.12 330.99 6,751.46 6,701.14 14,225.09 2,599.22 6,017,976.24 390,825.04 1.41 9,226.30 MWD+IFR-AK-CAZ-SC(4) 18,768.41 88.18 328.74 6,755.44 6,705.12 14,309.01 2,550.50 6,018,060.88 390,777.59 2.56 9,321.91 MWD+IFR-AK-CAZ-SC(4) 18,863.39 89.67 324.92 6,757.23 6,706.91 14,388.48 2,498.56 6,018,141.12 390,726.84 4.32 9,416.18 MWD+IFR-AK-CAZ-SC(4) 18,959.08 86.64 323.66 6,760.31 6,709.99 14,466.13 2,442.74 6,018,219.59 390,672.20 3.43 9,511.53 MWD+IFR-AK-CAZ-SC(4) 19,055.04 88.12 323.26 6,764.69 6,714.37 14,543.15 2,385.67 6,018,297.44 390,616.30 1.60 9,607.22 MWD+IFR-AK-CAZ-SC(4) 19,150.67 89.11 323.10 6,767.00 6,716.68 14,619.68 2,328.38 6,018,374.82 390,560.16 1.05 9,702.67 MWD+IFR-AK-CAZ-SC(4) 19,246.25 88.97 320.63 6,768.61 6,718.29 14,694.84 2,269.37 6,018,450.85 390,502.29 2.59 9,798.18 MWD+IFR-AK-CAZ-SC(4) 4/23/2012 11:38:10AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips r0•' Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119 Survey Calculation Method: Minimum Curvature Design: CD3-119 Database: EDM v16 Prod 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 19,341.44 87.96 317.99 6,771.16 6,720.84 14,766.98 2,207.33 6,018,523.91 390,441.36 2.97 9,893.32 MWD+IFR-AK-CAZ-SC(4) 19,375.00 87.96 317.99 6,772.35 6,722.03 14,791.90 2,184.89 6,018,549.16 390,419.29 0.00 9,926.84 PROJECTED to TD I 4/23/2012 11.38:10AM Page 8 COMPASS 2003.16 Build 69 7 1 ConocoPhillips(Alaska) Inc. Western North Slope ' CD3 Fiord Pad CD3-119PB1 501032065370 f 1 ''',67 t. 11 Sperry r3rillinct Definitive Survey Report ort 23 April, 2012 11 0 1 p V1 VVi 14i I a HALLIBURTON mit, -L . AVIIIIIINT AM la Mt . Sperry Drilling 1 €aid 6 ConocoPhillips ✓ Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119PB1 Survey Calculation Method: Minimum Curvature Design: CD3-119PB1 Database: EDM v16 Prod 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 CD3-119 Well Position +N/-S 0.00 ft Northing: 6,003,792.97 ft Latitude: 70°25'9.488 N +E/-W 0.00 ft Easting: 388,012.95 ft Longitude: 150°54'44.282 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft Wellbore CD3-119PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (') (nT) BGGM2011 2/14/2012 15.80 79.83 57,345 Design CD3-119PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 37.52 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 37.52 0.00 0.00 27.02 Survey Program Date 4/23/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 89.00 550.00 CD3-119PB1 Gyro(CD3-119PB1) CB-GYRO-SS Camera based gyro single shot 2/29/2012 12:C 579.05 15,545.73 CD3-119PB1 (MWD)(CD3-119PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/26/2012 12:C 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 37.52 0.00 0.00 37.52 -12.80 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 UNDEFINED 89.00 0.19 82.38 89.00 38.68 0.01 0.08 6,003,792.98 388,013.03 0.37 0.05 CB-GYR0-SS(1) 184.00 1.41 334.93 183.99 133.67 1.09 -0.25 6,003,794.06 388,012.71 1.56 0.86 CB-GYRO-SS(1) 275.00 3.88 326.15 274.89 224.57 4.66 -2.44 6,003,797.67 388,010.57 2.74 3.04 CB-GYRO-SS(1) 369.00 5.04 327.65 368.60 318.28 10.79 -6.43 6,003,803.86 388,006.69 1.24 6.70 CB-GYRO-SS(1) 461.00 5.51 338.53 460.21 409.89 18.32 -10.20 6,003,811.43 388,003.02 1.20 11.68 CB-GYRO-SS(1) 550.00 6.83 356.01 548.70 498.38 27.57 -12.14 6,003,820.72 388,001.23 2.56 19.05 CB-GYRO-SS(1) 579.05 7.10 353.68 577.54 527.22 31.08 -12.45 6,003,824.23 388,000.96 1.35 22.03 MWD+IFR-AK-CAZ-SC(2) 672.55 8.77 7.13 670.15 619.83 43.90 -12.21 6,003,837.04 388,001.40 2.66 33.56 MWD+IFR-AK-CAZ-SC(2) 765.63 11.04 12.22 761.84 711.52 59.65 -9.44 6,003,852.75 388,004.41 2.61 48.85 MWD+IFR-AK-CAZ-SC(2) 858.85 14.25 10.37 852.78 802.46 79.67 -5.48 6,003,872.70 388,008.66 3.47 68.48 MWD+IFR-AK-CAZ-SC(2) 950.61 19.05 10.88 940.67 890.35 105.50 -0.62 6,003,898.45 388,013.91 5.23 93.70 MWD+IFR-AK-CAZ-SC(2) 1,046.30 22.70 9.98 1,030.07 979.75 139.03 5.53 6,003,931.89 388,020.56 3.83 126.37 MWD+IFR-AK-CAZ-SC(2) 4/23/2012 11:36:07AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119PB1 Survey Calculation Method: Minimum Curvature Design: CD3-119PB1 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W . Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 1,139.52 23.21 9.34 1,115.90 1,065.58 174.87 11.63 6,003,967.63 388,027.20 0.61 161.06 MWD+IFR-AK-CAZ-SC(2) 1,233.55 24.07 7.50 1,202.04 1,151.72 212.16 17.14 6,004,004.83 388,033.27 1.20 196.79 MWD+IFR-AK-CAZ-SC(2) 1,327.20 26.02 5.77 1,286.88 1,236.56 251.54 21.70 6,004,044.13 388,038.41 2.22 233.94 MWD+IFR-AK-CAZ-SC(2) 1,420.62 30.47 6.38 1,369.16 1,318.84 295.49 26.39 6,004,088.00 388,043.77 4.77 275.23 MWD+IFR-AK-CAZ-SC(2) 1,513.13 35.30 4.68 1,446.83 1,396.51 345.47 31.18 6,004,137.90 388,049.31 5.32 321.93 MWD+IFR-AK-CAZ-SC(2) 1,608.06 40.40 6.01 1,521.76 1,471.44 403.44 36.64 6,004,195.78 388,055.64 5.44 376.05 MWD+IFR-AK-CAZ-SC(2) 1,703.87 44.97 8.04 1,592.17 1,541.85 467.88 44.63 6,004,260.08 388,064.59 4.98 437.09 MWD+IFR-AK-CAZ-SC(2) 1,797.28 48.95 10.26 1,655.92 1,605.60 535.25 55.53 6,004,327.28 388,076.50 4.60 502.05 MWD+IFR-AK-CAZ-SC(2) 1,891.94 52.19 12.28 1,716.04 1,665.72 606.94 69.84 6,004,398.74 388,091.88 3.80 572.42 MWD+IFR-AK-CAZ-SC(2) 1,985.64 53.40 14.99 1,772.70 1,722.38 679.45 87.45 6,004,470.97 388,110.57 2.64 645.01 MWD+IFR-AK-CAZ-SC(2) 2,081.01 53.52 20.62 1,829.51 1,779.19 752.35 110.86 6,004,543.50 388,135.08 4.74 720.59 MWD+IFR-AK-CAZ-SC(2) 2,174.34 54.90 20.63 1,884.09 1,833.77 823.20 137.53 6,004,613.94 388,162.80 1.48 795.83 MWD+IFR-AK-CAZ-SC(2) 2,270.36 59.16 21.90 1,936.33 1,886.01 898.24 166.76 6,004,688.53 388,193.15 4.57 875.96 MWD+IFR-AK-CAZ-SC(2) 2,363.88 62.95 21.73 1,981.59 1,931.27 974.21 197.16 6,004,764.03 388,224.69 4.06 957.44 MWD+IFR-AK-CAZ-SC(2) 2,455.83 65.78 24.17 2,021.37 1,971.05 1,050.52 229.50 6,004,839.84 388,258.16 3.90 1,040.12 MWD+IFR-AK-CAZ-SC(2) 2,549.60 66.13 23.20 2,059.58 2,009.26 1,128.94 263.90 6,004,917.73 388,293.73 1.02 1,125.61 MWD+IFR-AK-CAZ-SC(2) 2,643.70 66.96 24.94 2,097.03 2,046.71 1,207.75 299.11 6,004,996.00 388,330.12 1.91 1,211.81 MWD+IFR-AK-CAZ-SC(2) 2,739.27 67.90 24.02 2,133.71 2,083.39 1,288.07 335.67 6,005,075.75 388,367.88 1.33 1,299.97 MWD+IFR-AK-CAZ-SC(2) 2,834.26 68.24 24.85 2,169.19 2,118.87 1,368.29 372.13 6,005,155.41 388,405.53 0.89 1,388.00 MWD+IFR-AK-CAZ-SC(2) 2,927.75 68.17 25.19 2,203.90 2,153.58 1,446.95 408.84 6,005,233.50 388,443.41 0.35 1,474.75 MWD+IFR-AK-CAZ-SC(2) 3,023.05 67.51 25.16 2,239.85 2,189.53 1,526.83 446.38 6,005,312.80 388,482.15 0.69 1,562.97 MWD+IFR-AK-CAZ-SC(2) 3,118.96 67.67 24.59 2,276.41 2,226.09 1,607.27 483.68 6,005,392.67 388,520.64 0.57 1,651.57 MWD+IFR-AK-CAZ-SC(2) 3,210.56 67.05 27.24 2,311.68 2,261.36 1,683.30 520.62 6,005,468.13 388,558.72 2.75 1,736.09 MWD+IFR-AK-CAZ-SC(2) 3,305.03 66.56 30.37 2,348.89 2,298.57 1,759.38 562.45 6,005,543.57 388,601.68 3.09 1,822.86 MWD+IFR-AK-CAZ-SC(2) 3,398.79 67.95 30.65 2,385.14 2,334.82 1,833.88 606.35 6,005,617.39 388,646.68 1.51 1,909.17 MWD+IFR-AK-CAZ-SC(2) 3,494.41 66.38 29.92 2,422.25 2,371.93 1,909.97 650.79 6,005,692.80 388,692.26 1.79 1,997.15 MWD+IFR-AK-CAZ-SC(2) 3,589.41 66.92 30.57 2,459.90 2,409.58 1,985.32 694.72 6,005,767.47 388,737.31 0.85 2,084.23 MWD+IFR-AK-CAZ-SC(2) 3,650.35 66.90 31.08 2,483.80 2,433.48 2,033.46 723.45 6,005,815.17 388,766.76 0.78 2,140.16 MWD+IFR-AK-CAZ-SC(2) 10-3/4"x 13-1/2" 3,689.05 66.89 31.41 2,498.99 2,448.67 2,063.89 741.91 6,005,845.32 388,785.67 0.78 2,175.66 MWD+IFR-AK-CAZ-SC(2) 3,723.25 66.43 30.97 2,512.54 2,462.22 2,090.75 758.18 6,005,871.93 388,802.34 1.79 2,206.98 MWD+IFR-AK-CAZ-SC(2) 3,818.25 67.72 32.45 2,549.55 2,499.23 2,165.18 804.17 6,005,945.65 388,849.44 1.98 2,294.18 MWD+IFR-AK-CAZ-SC(2) 3,912.40 68.13 32.43 2,584.93 2,534.61 2,238.81 850.97 6,006,018.57 388,897.33 0.44 2,381.04 MWD+IFR-AK-CAZ-SC(2) 4,006.95 67.71 31.56 2,620.47 2,570.15 2,313.12 897.39 6,006,092.16 388,944.86 0.96 2,468.32 MWD+IFR-AK-CAZ-SC(2) 4,099.84 67.21 31.88 2,656.08 2,605.76 2,386.10 942.50 6,006,164.45 388,991.05 0.63 2,553.83 MWD+IFR-AK-CAZ-SC(2) 4,193.91 68.07 30.74 2,691.87 2,641.55 2,460.42 987.71 6,006,238.09 389,037.37 1.45 2,640.58 MWD+IFR-AK-CAZ-SC(2) 4,288.36 67.79 31.40 2,727.35 2,677.03 2,535.39 1,032.88 6,006,312.37 389,083.65 0.71 2,727.89 MWD+IFR-AK-CAZ-SC(2) 4,383.91 67.49 31.67 2,763.70 2,713.38 2,610.71 1,079.09 6,006,386.97 389,130.99 0.41 2,815.98 MWD+IFR-AK-CAZ-SC(2) 4,476.78 68.16 30.89 2,798.76 2,748.44 2,684.21 1,123.75 6,006,459.79 389,176.74 1.06 2,901.74 MWD+IFR-AK-CAZ-SC(2) 4,571.43 68.48 25.41 2,833.75 2,783.43 2,761.72 1,165.22 6,006,536.67 389,219.36 5.39 2,989.64 MWD+IFR-AK-CAZ-SC(2) 4/23/2012 11:36:07AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119PB1 Survey Calculation Method: Minimum Curvature Design: CD3-119PB1 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/10(y) (ft) Survey Tool Name 4,665.49 68.47 20.35 2,868.28 2,817.96 2,842.31 1,199.22 6,006,616.72 389,254.57 5.00 3,076.87 MWD+IFR-AK-CAZ-SC(2) 4,759.23 68.40 22.67 2,902.74 2,852.42 2,923.41 1,231.18 6,006,697.33 389,287.74 2.30 3,163.64 MWD+IFR-AK-CAZ-SC(2) 4,853.06 68.41 22.73 2,937.27 2,886.95 3,003.89 1,264.85 6,006,777.29 389,322.61 0.06 3,250.64 MWD+IFR-AK-CAZ-SC(2) 4,944.62 67.98 24.59 2,971.28 2,920.96 3,081.75 1,298.96 6,006,854.62 389,357.88 1.94 3,335.49 MWD+IFR-AK-CAZ-SC(2) 5,038.98 68.20 24.17 3,006.49 2,956.17 3,161.49 1,335.10 6,006,933.80 389,395.21 0.47 3,422.94 MWD+IFR-AK-CAZ-SC(2) 5,134.72 68.17 26.65 3,042.07 2,991.75 3,241.77 1,373.24 6,007,013.49 389,434.54 2.41 3,511.78 MWD+IFR-AK-CAZ-SC(2) 5,228.96 67.86 29.89 3,077.36 3,027.04 3,318.72 1,414.62 6,007,089.81 389,477.07 3.20 3,599.14 MWD+IFR-AK-CAZ-SC(2) 5,321.95 68.98 31.29 3,111.56 3,061.24 3,393.15 1,458.62 6,007,163.57 389,522.18 1.85 3,685.44 MWD+IFR-AK-CAZ-SC(2) 5,417.30 68.50 32.38 3,146.14 3,095.82 3,468.64 1,505.49 6,007,238.34 389,570.17 1.18 3,773.98 MWD+IFR-AK-CAZ-SC(2) 5,509.83 68.08 31.23 3,180.37 3,130.05 3,541.70 1,550.80 6,007,310.70 389,616.57 1.24 3,859.65 MWD+IFR-AK-CAZ-SC(2) 5,605.18 68.11 31.20 3,215.94 3,165.62 3,617.36 1,596.65 6,007,385.66 389,663.54 0.04 3,947.88 MWD+IFR-AK-CAZ-SC(2) 5,699.75 68.44 30.49 3,250.95 3,200.63 3,692.78 1,641.69 6,007,460.40 389,709.70 0.78 4,035.53 MWD+IFR-AK-CAZ-SC(2) 5,795.47 68.51 31.63 3,286.07 3,235.75 3,769.06 1,687.63 6,007,535.97 389,756.78 1.11 4,124.35 MWD+IFR-AK-CAZ-5C(2) 5,889.63 68.02 33.28 3,320.94 3,270.62 3,842.86 1,734.56 6,007,609.05 389,804.81 1.71 4,211.42 MWD+IFR-AK-CAZ-SC(2) 5,982.05 68.98 32.77 3,354.81 3,304.49 3,914.96 1,781.42 6,007,680.43 389,852.75 1.16 4,296.94 MWD+IFR-AK-CAZ-SC(2) 6,078.37 68.04 31.91 3,390.10 3,339.78 3,990.68 1,829.37 6,007,755.41 389,901.82 1.28 4,386.17 MWD+IFR-AK-CAZ-SC(2) 6,173.12 68.46 31.53 3,425.21 3,374.89 4,065.54 1,875.64 6,007,829.56 389,949.20 0.58 4,473.88 MWD+IFR-AK-CAZ-SC(2) 6,267.53 68.27 32.68 3,460.02 3,409.70 4,139.87 1,922.28 6,007,903.19 389,996.95 1.15 4,561.29 MWD+IFR-AK-CAZ-SC(2) 6,360.39 68.72 32.04 3,494.06 3,443.74 4,212.85 1,968.52 6,007,975.46 390,044.27 0.80 4,647.31 MWD+IFR-AK-CAZ-SC(2) 6,453.89 68.08 32.53 3,528.48 3,478.16 4,286.35 2,014.95 6,008,048.24 390,091.80 0.84 4,733.88 MWD+IFR-AK-CAZ-SC(2) 6,548.65 68.06 31.74 3,563.87 3,513.55 4,360.78 2,061.71 6,008,121.96 390,139.66 0.77 4,821.43 MWD+IFR-AK-CAZ-SC(2) 6,643.96 68.33 30.75 3,599.27 3,548.95 4,436.44 2,107.61 6,008,196.91 390,186.69 1.01 4,909.68 MWD+IFR-AK-CAZ-SC(2) 6,737.04 68.18 31.41 3,633.75 3,583.43 4,510.48 2,152.24 6,008,270.27 390,232.42 0.68 4,995.92 MWD+IFR-AK-CAZ-SC(2) 6,832.04 68.01 32.71 3,669.20 3,618.88 4,585.18 2,199.02 6,008,344.25 390,280.32 1.28 5,083.72 MWD+IFR-AK-CAZ-SC(2) 6,926.90 67.85 32.81 3,704.84 3,654.52 4,659.11 2,246.59 6,008,417.45 390,328.99 0.19 5,171.19 MWD+IFR-AK-CAZ-SC(2) 7,020.94 68.46 33.40 3,739.83 3,689.51 4,732.22 2,294.27 6,008,489.84 390,377.75 0.87 5,257.98 MWD+IFR-AK-CAZ-SC(2) 7,116.31 67.66 31.38 3,775.47 3,725.15 4,806.92 2,341.66 6,008,563.81 390,426.25 2.14 5,346.05 MWD+IFR-AK-CAZ-SC(2) 7,209.20 68.08 29.03 3,810.47 3,760.15 4,881.27 2,384.94 6,008,637.50 390,470.64 2.39 5,431.96 MWD+IFR-AK-CAZ-SC(2) 7,301.77 67.87 28.19 3,845.18 3,794.86 4,956.61 2,426.03 6,008,712.20 390,512.85 0.87 5,517.74 MWD+IFR-AK-CAZ-SC(2) 7,398.27 67.82 28.09 3,881.57 3,831.25 5,035.42 2,468.18 6,008,790.37 390,556.18 0.11 5,607.09 MWD+IFR-AK-CAZ-SC(2) 7,493.99 67.71 27.59 3,917.79 3,867.47 5,113.77 2,509.56 6,008,868.08 390,598.72 0.50 5,695.69 MWD+IFR-AK-CAZ-SC(2) 7,587.98 67.71 28.50 3,953.44 3,903.12 5,190.52 2,550.45 6,008,944.20 390,640.75 0.90 5,782.64 MWD+IFR-AK-CAZ-SC(2) 7,680.78 68.24 29.44 3,988.25 3,937.93 5,265.78 2,592.12 6,009,018.82 390,683.54 1.10 5,868.61 MWD+IFR-AK-CAZ-SC(2) 7,773.38 68.26 29.94 4,022.56 3,972.24 5,340.50 2,634.72 6,009,092.89 390,727.25 0.50 5,954.53 MWD+IFR-AK-CAZ-SC(2) 7,869.47 67.86 30.05 4,058.46 4,008.14 5,417.69 2,679.28 6,009,169.40 390,772.96 0.43 6,043.54 MWD+IFR-AK-CAZ-SC(2) 7,963.02 67.89 31.75 4,093.70 4,043.38 5,492.05 2,723.78 6,009,243.07 390,818.57 1.68 6,130.00 MWD+IFR-AK-CAZ-SC(2) 8,055.17 67.59 32.63 4,128.61 4,078.29 5,564.22 2,769.21 6,009,314.55 390,865.07 0.94 6,214.93 MWD+IFR-AK-CAZ-5C(2) 8,151.65 67.71 32.61 4,165.29 4,114.97 5,639.38 2,817.31 6,009,388.97 390,914.29 0.13 6,303.74 MWD+IFR-AK-CAZ-SC(2) 8,244.14 67.45 31.94 4,200.57 4,150.25 5,711.67 2,862.97 6,009,460.56 390,961.02 0.73 6,388.88 MWD+IFR-AK-CAZ-SC(2) 8,339.04 67.88 32.66 4,236.63 4,186.31 5,785.86 2,909.87 6,009,534.04 391,009.03 0.84 6,476.28 MWD+IFR-AK-CAZ-SC(2) 4/23/2012 11:36:07AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119PB1 Survey Calculation Method: Minimum Curvature Design: CD3-119PB1 Database: EDM v16 Prod 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 8,433.48 67.90 32.27 4,272.18 4,221.86 5,859.68 2,956.84 6,009,607.14 391,057.10 0.38 6,563.38 MWD+IFR-AK-CAZ-SC(2) 8,527.46 67.81 32.68 4,307.61 4,257.29 5,933.12 3,003.58 6,009,679.86 391,104.93 0.42 6,650.04 MWD+IFR-AK-CAZ-SC(2) 8,621.74 68.00 33.88 4,343.07 4,292.75 6,006.15 3,051.51 6,009,752.15 391,153.95 1.20 6,736.87 MWD+IFR-AK-CAZ-SC(2) 8,716.27 68.08 35.09 4,378.42 4,328.10 6,078.41 3,101.15 6,009,823.66 391,204.66 1.19 6,823.80 MWD+IFR-AK-CAZ-SC(2) 8,811.20 67.82 34.12 4,414.06 4,363.74 6,150.83 3,151.12 6,009,895.31 391,255.71 0.99 6,911.01 MWD+IFR-AK-CAZ-SC(2) 8,904.38 67.46 34.02 4,449.51 4,399.19 6,222.21 3,199.39 6,009,965.95 391,305.04 0.40 6,996.53 MWD+IFR-AK-CAZ-SC(2) 8,998.57 67.66 34.41 4,485.46 4,435.14 6,294.20 3,248.34 6,010,037.20 391,355.06 0.44 7,082.91 MWD+IFR-AK-CAZ-SC(2) 9,093.91 67.67 34.85 4,521.69 4,471.37 6,366.77 3,298.46 6,010,108.99 391,406.26 0.43 7,170.32 MWD+IFR-AK-CAZ-SC(2) 9,187.90 67.27 34.22 4,557.71 4,507.39 6,438.28 3,347.68 6,010,179.76 391,456.54 0.75 7,256.39 MWD+IFR-AK-CAZ-SC(2) 9,280.23 68.38 35.28 4,592.56 4,542.24 6,508.53 3,396.41 6,010,249.26 391,506.32 1.60 7,341.11 MWD+IFR-AK-CAZ-SC(2) 9,372.88 68.20 31.59 4,626.84 4,576.52 6,580.35 3,443.83 6,010,320.35 391,554.80 3.71 7,426.63 MWD+IFR-AK-CAZ-SC(2) 9,468.15 67.79 30.20 4,662.54 4,612.22 6,656.14 3,489.19 6,010,395.45 391,601.29 1.42 7,514.75 MWD+IFR-AK-CAZ-SC(2) 9,563.96 67.91 31.00 4,698.66 4,648.34 6,732.52 3,534.36 6,010,471.14 391,647.60 0.78 7,603.32 MWD+IFR-AK-CAZ-SC(2) 9,658.23 67.76 30.48 4,734.23 4,683.91 6,807.56 3,578.98 6,010,545.49 391,693.34 0.54 7,690.44 MWD+IFR-AK-CAZ-SC(2) 9,752.65 67.63 30.80 4,770.06 4,719.74 6,882.72 3,623.50 6,010,619.97 391,738.98 0.34 7,777.62 MWD+IFR-AK-CAZ-SC(2) 9,846.55 68.23 31.69 4,805.34 4,755.02 6,957.11 3,668.64 6,010,693.67 391,785.22 1.09 7,864.40 MWD+IFR-AK-CAZ-SC(2) 9,938.61 68.07 30.02 4,839.61 4,789.29 7,030.46 3,712.46 6,010,766.35 391,830.13 1.69 7,949.65 MWD+IFR-AK-CAZ-SC(2) 10,032.61 67.88 29.58 4,874.86 4,824.54 7,106.08 3,755.77 6,010,841.30 391,874.56 0.48 8,036.69 MWD+IFR-AK-CAZ-SC(2) 10,125.87 68.45 30.16 4,909.55 4,859.23 7,181.15 3,798.88 6,010,915.71 391,918.80 0.84 8,123.15 MWD+IFR-AK-CAZ-SC(2) 10,220.16 67.51 29.96 4,944.90 4,894.58 7,256.80 3,842.67 6,010,990.69 391,963.71 1.02 8,210.44 MWD+IFR-AK-CAZ-SC(2) 10,313.02 68.31 30.37 4,979.82 4,929.50 7,331.19 3,885.90 6,011,064.42 392,008.05 0.95 8,296.35 MWD+IFR-AK-CAZ-SC(2) 10,407.97 68.29 30.24 5,014.93 4,964.61 7,407.36 3,930.42 6,011,139.90 392,053.70 0.13 8,384.42 MWD+IFR-AK-CAZ-SC(2) 10,500.39 68.19 29.16 5,049.19 4,998.87 7,481.91 3,972.95 6,011,213.80 392,097.34 1.09 8,470.16 MWD+IFR-AK-CAZ-SC(2) 10,593.95 67.96 28.93 5,084.12 5,033.80 7,557.79 4,015.08 6,011,289.03 392,140.61 0.34 8,556.90 MWD+IFR-AK-CAZ-SC(2) 10,688.77 67.88 29.34 5,119.77 5,069.45 7,634.54 4,057.86 6,011,365.13 392,184.53 0.41 8,644.71 MWD+IFR-AK-CAZ-SC(2) 10,782.89 67.68 29.09 5,155.36 5,105.04 7,710.59 4,100.39 6,011,440.52 392,228.19 0.32 8,731.77 MWD+IFR-AK-CAZ-SC(2) 10,876.96 67.92 28.87 5,190.90 5,140.58 7,786.78 4,142.59 6,011,516.06 392,271.52 0.33 8,818.82 MWD+IFR-AK-CAZ-SC(2) 10,971.72 67.87 28.44 5,226.56 5,176.24 7,863.82 4,184.69 6,011,592.46 392,314.77 0.42 8,906.58 MWD+IFR-AK-CAZ-SC(2) 11,066.60 67.69 28.07 5,262.44 5,212.12 7,941.19 4,226.27 6,011,669.19 392,357.50 0.41 8,994.39 MWD+IFR-AK-CAZ-SC(2) 11,161.05 67.76 29.39 5,298.25 5,247.93 8,017.83 4,268.28 6,011,745.18 392,400.65 1.30 9,081.75 MWD+IFR-AK-CAZ-SC(2) 11,255.84 67.64 31.02 5,334.22 5,283.90 8,093.62 4,312.40 6,011,820.29 392,445.90 1.60 9,169.31 MWD+IFR-AK-CAZ-SC(2) 11,350.32 68.26 30.65 5,369.69 5,319.37 8,168.81 4,357.29 6,011,894.80 392,491.91 0.75 9,256.69 MWD+IFR-AK-CAZ-SC(2) 11,444.31 67.88 30.58 5,404.79 5,354.47 8,243.84 4,401.69 6,011,969.15 392,537.42 0.41 9,343.71 MWD+IFR-AK-CAZ-SC(2) 11,538.84 68.45 30.67 5,439.95 5,389.63 8,319.35 4,446.39 6,012,043.97 392,583.25 0.61 9,431.28 MWD+IFR-AK-CAZ-SC(2) 11,633.22 67.85 30.08 5,475.07 5,424.75 8,394.93 4,490.68 6,012,118.87 392,628.67 0.86 9,518.73 MWD+IFR-AK-CAZ-SC(2) 11,727.54 68.00 30.49 5,510.52 5,460.20 8,470.40 4,534.76 6,012,193.67 392,673.87 0.43 9,605.99 MWD+IFR-AK-CAZ-SC(2) 11,821.57 68.20 31.48 5,545.59 5,495.27 8,545.20 4,579.68 6,012,267.78 392,719.90 1.00 9,693.03 MWD+IFR-AK-CAZ-SC(2) 11,915.42 68.48 29.89 5,580.24 5,529.92 8,620.21 4,624.19 6,012,342.10 392,765.52 1.60 9,780.07 MWD+IFR-AK-CAZ-SC(2) 12,009.86 67.69 30.22 5,615.48 5,565.16 8,696.04 4,668.07 6,012,417.26 392,810.53 0.90 9,867.56 MWD+IFR-AK-CAZ-SC(2) 12,103.07 67.67 30.34 5,650.88 5,600.56 8,770.50 4,711.54 6,012,491.06 392,855.12 0.12 9,953.65 MWD+IFR-AK-CAZ-SC(2) 4/23/2012 11:36:07AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-119 Project: Western North Slope TVD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Site: CD3 Fiord Pad MD Reference: CD3-119 @ 50.32ft(Doyon 19(12.8+37.52)) Well: CD3-119 North Reference: True Wellbore: CD3-119PB1 Survey Calculation Method: Minimum Curvature Design: CD3-119PB1 Database: EDM v16 Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,195.20 68.38 29.66 5,685.36 5,635.04 8,844.49 4,754.26 6,012,564.39 392,898.94 1.03 10,038.97 MWD+IFR-AK-CAZ-SC(2) 12,288.62 68.04 28.67 5,720.04 5,669.72 8,920.24 4,796.53 6,012,639.49 392,942.34 1.05 10,125.65 MWD+IFR-AK-CAZ-SC(2) 12,383.59 68.47 27.79 5,755.22 5,704.90 8,997.96 4,838.26 6,012,716.57 392,985.22 0.97 10,213.84 MWD+IFR-AK-CAZ-SC(2) 12,478.29 67.94 27.59 5,790.38 5,740.06 9,075.82 4,879.12 6,012,793.80 393,027.24 0.59 10,301.77 MWD+IFR-AK-CAZ-SC(2) 12,572.21 67.79 26.81 5,825.77 5,775.45 9,153.20 4,918.88 6,012,870.56 393,068.16 0.79 10,388.76 MWD+IFR-AK-CAZ-SC(2) 12,667.85 67.10 27.21 5,862.46 5,812.14 9,231.89 4,958.99 6,012,948.64 393,109.44 0.82 10,477.09 MWD+IFR-AK-CAZ-SC(2) 12,761.37 66.76 26.67 5,899.10 5,848.78 9,308.59 4,997.98 6,013,024.74 393,149.57 0.64 10,563.13 MWD+IFR-AK-CAZ-SC(2) 12,854.30 67.00 24.29 5,935.60 5,885.28 9,385.74 5,034.74 6,013,101.32 393,187.48 2.37 10,648.55 MWD+IFR-AK-CAZ-SC(2) 12,951.45 66.67 22.88 5,973.81 5,923.49 9,467.59 5,070.48 6,013,182.62 393,224.44 1.38 10,737.71 MWD+IFR-AK-CAZ-SC(2) 13,044.44 66.51 21.18 6,010.76 5,960.44 9,546.69 5,102.48 6,013,261.23 393,257.62 1.69 10,822.72 MWD+IFR-AK-CAZ-SC(2) 13,139.58 67.59 18.07 6,047.87 5,997.55 9,629.20 5,131.89 6,013,343.28 393,288.27 3.22 10,909.58 MWD+IFR-AK-CAZ-SC(2) 13,233.25 68.06 16.33 6,083.22 6,032.90 9,712.06 5,157.54 6,013,425.73 393,315.15 1.79 10,995.05 MWD+IFR-AK-CAZ-SC(2) 13,328.47 68.91 12.15 6,118.16 6,067.84 9,797.90 5,179.32 6,013,511.23 393,338.21 4.18 11,081.41 MWD+IFR-AK-CAZ-SC(2) 13,422.30 69.50 8.07 6,151.48 6,101.16 9,884.23 5,194.70 6,013,597.32 393,354.89 4.11 11,165.31 MWD+IFR-AK-CAZ-SC(2) 13,517.03 68.93 3.94 6,185.11 6,134.79 9,972.29 5,203.97 6,013,685.21 393,365.48 4.12 11,247.96 MWD+IFR-AK-CAZ-SC(2) 13,610.49 71.27 359.79 6,216.93 6,166.61 10,060.09 5,206.81 6,013,772.96 393,369.63 4.87 11,327.47 MWD+IFR-AK-CAZ-SC(2) 13,704.91 72.83 355.92 6,246.04 6,195.72 10,149.83 5,203.43 6,013,862.73 393,367.60 4.23 11,405.88 MWD+IFR-AK-CAZ-SC(2) 13,800.85 73.98 352.37 6,273.45 6,223.13 10,241.27 5,194.05 6,013,954.30 393,359.59 3.74 11,483.08 MWD+IFR-AK-CAZ-SC(2) 13,895.76 73.20 349.15 6,300.27 6,249.95 10,331.12 5,179.44 6,014,044.35 393,346.33 3.36 11,556.48 MWD+IFR-AK-CAZ-SC(2) 13,989.89 73.37 345.22 6,327.35 6,277.03 10,419.01 5,159.44 6,014,132.52 393,327.66 4.00 11,625.69 MWD+IFR-AK-CAZ-SC(2) 14,083.83 72.89 341.60 6,354.62 6,304.30 10,505.15 5,133.78 6,014,219.02 393,303.30 3.72 11,690.77 MWD+IFR-AK-CAZ-SC(2) 14,178.68 72.50 337.73 6,382.85 6,332.53 10,590.04 5,102.32 6,014,304.37 393,273.12 3.92 11,752.11 MWD+IFR-AK-CAZ-SC(2) 14,270.18 72.41 333.34 6,410.44 6,360.12 10,669.43 5,066.21 6,014,384.29 393,238.20 4.58 11,806.42 MWD+IFR-AK-CAZ-SC(2) 14,364.44 70.87 327.91 6,440.15 6,389.83 10,747.36 5,022.36 6,014,462.86 393,195.53 5.71 11,855.93 MWD+IFR-AK-CAZ-SC(2) 14,451.73 69.88 323.75 6,469.48 6,419.16 10,815.37 4,976.20 6,014,531.55 393,150.40 4.63 11,895.55 MWD+IFR-AK-CAZ-SC(2) 14,544.87 69.81 323.20 6,501.57 6,451.25 10,885.64 4,924.16 6,014,602.58 393,099.42 0.56 11,934.50 MWD+IFR-AK-CAZ-SC(2) 14,636.42 70.33 322.56 6,532.78 6,482.46 10,954.26 4,872.22 6,014,671.97 393,048.52 0.87 11,972.04 MWD+IFR-AK-CAZ-SC(2) 14,731.86 70.06 319.66 6,565.12 6,514.80 11,024.15 4,815.85 6,014,742.69 392,993.22 2.87 12,008.69 MWD+IFR-AK-CAZ-SC(2) 14,825.94 70.10 320.10 6,597.18 6,546.86 11,091.78 4,758.86 6,014,811.17 392,937.24 0.44 12,043.05 MWD+IFR-AK-CAZ-SC(2) 14,920.72 70.45 320.27 6,629.16 6,578.84 11,160.31 4,701.73 6,014,880.54 392,881.16 0.41 12,078.15 MWD+IFR-AK-CAZ-SC(2) 15,014.44 69.99 318.70 6,660.88 6,610.56 11,227.36 4,644.44 6,014,948.43 392,824.88 1.65 12,111.85 MWD+IFR-AK-CAZ-SC(2) 15,110.06 69.94 319.07 6,693.64 6,643.32 11,295.04 4,585.37 6,015,016.98 392,766.84 0.37 12,145.30 MWD+IFR-AK-CAZ-SC(2) 15,205.13 69.86 321.57 6,726.32 6,676.00 11,363.74 4,528.37 6,015,086.53 392,710.88 2.47 12,180.61 MWD+IFR-AK-CAZ-SC(2) 15,299.63 70.42 320.77 6,758.42 6,708.10 11,432.98 4,472.64 6,015,156.59 392,656.20 0.99 12,216.97 MWD+IFR-AK-CAZ-SC(2) 15,393.28 69.54 321.09 6,790.48 6,740.16 11,501.29 4,417.18 6,015,225.72 392,601.78 0.99 12,252.64 MWD+IFR-AK-CAZ-SC(2) 15,487.54 69.29 321.08 6,823.62 6,773.30 11,569.95 4,361.75 6,015,295.20 392,547.39 0.27 12,288.62 MWD+IFR-AK-CAZ-SC(2) 15,545.73 67.88 320.73 6,844.87 6,794.55 11,611.99 4,327.59 6,015,337.74 392,513.87 2.49 12,310.55 MWD+IFR-AK-CAZ-SC(2) 15,613.00 67.88 320.73 6,870.20 6,819.88 11,660.24 4,288.15 6,015,386.57 392,475.15 0.00 12,335.61 PROJECTED to TD 4/23/2012 11:36:07AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary We/new Web Reporting Report Well Name: CD3-119 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 2/24/2012 9:00:00 AM Rig Release: 4/23/2012 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/23/2012 24 hr Summary Prepare to move. Move pipe shed, move MI Swaco ball mill 30'away f/rig, move pits 20'away f/rig,skid rig floor 65+',prep cellar walls, lift walls, lift stomper feet, move rig off hole towards outside edge of pad, set matting boards, maneuver rig towards CD3-119. 16:00 18:15 2.25 MIRU MOVE RURD P Prepare rig f/move f/CD3-128 to CD3-119. MI Swaco ball mill preparing there unit. 18:15 18:30 0.25 MIRU MOVE SFTY P Pre job safety meeting w/MI Swaco hands,truck driver and pusher, Doyon pit watcher and driller,on moving ball mill away f/rig. 18:30 19:30 1.00 MIRU MOVE MOB P Jack up ball mill, back SOW (Petunia)under load, set down on truck, secure winch line. Move ball mill ahead 30'.Take load off truck. Standby f/rig move. 19:30 20:00 0.50 MIRU MOVE SFTY P Pre job safety meeting w/rig crew on moving. 20:00 00:00 4.00 MIRU MOVE MOB P Prepare to move pits 20'away f/rig sub.Jack up,then move pits.Skid rig floor 65+'. Raise cellar wind walls, Raise stomper feet,secure same. Jack up rig. Move rig off well, move ahead to edge of pad.Setting mats. Maneuver rig towards CD3-119. Note: Move f/CD3-128 to CD3-119 is 180'in line. 02/24/2012 Continue moving rig f/CD3-128 to CD3-119(180').Accept rig @ 0900 hrs 2/24/2012. Moving MI Swaco ball ®mill. Rig up, PU a 16 3/4"riser-flange not same as adapter on starting head, lay down riser, PU another riser, nipple up 16-3/4"riser-ok, Sperry Sun orient gyro tools,finish nippling up riser. 00:00 01:45 1.75 MIRU MOVE MOB P Continue to move sub f/CD3-128 to CD3-119(180'in line). Set rig down over well, check rig f/level-OK. Clean up cellar area of CD3-128. Note:Wells group installing parachute and heat to well CD3-128 to keep warm. 01:45 02:00 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving pits towards CD3-119. 02:00 03:00 1.00 MIRU MOVE MOB P Move pits f/CD3-128 to 25'away f/ sub @ CD3-119. Lower wind walls and cantilever support feet on sub. 03:00 03:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on changing bushings in support feet. 03:15 04:00 0.75 MIRU MOVE RURD P Rigging up to change bushings in both support feet.Two portable tioga heaters running in cellar area. Page 1 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving pipe shed to rig over hole @ CD119. 04:15 05:45 1.50 MIRU MOVE MOB P Move pipe shed and mate up to rig sub.Jack up to prepare to un-pin moving support bars. Preload cantilever support feet. 05:45 06:00 0.25 MIRU MOVE SFTY P Pre job safety meeting on skidding rig floor 65+'to drilling position. 06:00 07:00 1.00 MIRU MOVE MOB P Skid rig floor 65+'to drilling position. 07:00 07:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving Pits and motors. 07:15 08:00 0.75 MIRU MOVE MOB P Move pits and motors.Set complexs down. Set pipe shed down. Pre job safety meeting on moving MI Swaco Ball mill 0730-0800 hrs. 08:00 09:00 1.00 MIRU MOVE MOB P Moving MI Swaco ball mill with SOW (Petunia) Note: Doyon Rig 19 accepted @ 0900 hrs 2/24/2012. 09:00 12:00 3.00 MIRU MOVE RURD P Rigging up: Connect service lines, insulate cellar/rig floor.Take on water and diesel.Work on housekeeping. Moving MI Swaco ball mill with SOW(Petunia)-set down @ 1200 hrs. 12:00 14:30 2.50 MIRU MOVE RURD P Rigging up:Taking on water and diesel.Work on housekeeping. Rig up hoses in the pit room. Moving MI Swaco ball mill with SOW(Petunia). 14:30 16:30 2.00 MIRU MOVE RURD T Rig on Hi-line @ 1430 hrs.Trouble shoot electrical problem w/the top drive. Cable not correctly hooked up. Fixed problem. 16:30 18:00 1.50 MIRU MOVE RURD P Take on mud into pits.Change out mud bucket,air slips, change iron roughneck over to 5", load 105 jts of 5"drill pipe in the shed. 18:00 20:30 2.50 MIRU MOVE NUND T Pick up surface riser(16-3/4"2m)f/ CD3.The flange on the bottom of riser did not match the adapter on FMC starting head adapter. Discuss issue. Decision to pick up 16-3/4" riser f/CD-4. Note: Bolt circle on FMC's adapter correct(16-3/4"2m flange w/R65 ring gasket). 20:30 22:00 1.50 MIRU MOVE NUND P Lay down the CD-3 riser, Pick up the CD-4 riser. Nipple up,connect flow line, install(2)4"plugs on the riser, secure w/turn buckles. Note: RKB to ground level 37.52', RKB to the load shoulder of landing ring 36.75. 22:00 23:00 1.00 MIRU MOVE SRVY P Orient and calibrate Sperry Sun Gyro tool to North. 23:00 00:00 1.00 MIRU MOVE NUND P Continue to nipple up 16-3/4"riser. Page 2 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/25/2012 24 hr Summary PU/MU/stand back 35 stands of 5"dp, 5 stands of 5"HWDP, 1 stand of flex collars, attempt to blow air through top drive-no go,thaw out ice in kelly hose,fill hole,check f/leaks-ok,attempt to test mud lines to 3500 psi-IBOP would not close, MU clean out BHA, attempt to test mud lines-IBOP would not close,tighten kelly hose connection, repair sight glass on air dryer on the top drive,test mud lines to IBOP to 3500 psi, prepare to clean out ice in the conductor @ 52'. 00:00 00:15 0.25 SURFA( MOVE SFTY P Pre job safety meeting 00:15 00:30 0.25 SURFA( MOVE RURD P Install the mouse hole 00:30 04:30 4.00 SURFA( MOVE PULD P Pick up/standback 5"dp, using the mouse hole. 17 stands picked up. 04:30 05:00 0.50 SURFA( RIGMN1SVRG P Service rig. 05:00 11:15 6.25 SURFA( MOVE PULD P Continue to pick up/standback 5" dp, using the mouse hole. 18 stands picked up(total 35 stands). PU s 5 stands of 5"HWDP and(1)stand of flex drill collars. 11:15 12:00 0.75 SURFA( DRILL PULD P Pick up BHA componets to rig floor. Calibrate Schlumberger block height. 12:00 12:15 0.25 SURFA( DRILL SFTY P Pre job safety meeting 12:15 18:00 5.75 SURFA( RIGMNT RGRP T Blow air to mud pumps and top drive to verify clear.Top drive froze. Break off kelly hose, blow through top drive and kelly hose.Top drive clear, kelly hose restricted @ 55 feet. Steam kelly hose,thaw out. Make up kelly hose to the top drive. 18:00 19:30 1.50 0 30 SURFA( DRILL CIRC P Make up a stand of 5"drill pipe. Fill lines and hole.Check f/leaks-ok. Attempt to test mud line and kelly hose to 3500 psi. Unsuccessful, unable to close automatic IBOP. Blow down the top drive. Note:Tripped off high line @ 1720 hrs when Power Factor Corrector was put on line. Back on hi-line @ 1923 hrs with out power factor corrector. 19:30 19:45 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting 19:45 21:30 1.75 0 46 SURFA( DRILL PULD P Make up 13-1/2"Hughes MXL-1X bit (ser#5194925),Schlumberger SP Motor(1.83 deg bend), 15' NMLDC and crossover to 46'. 21:30 23:00 1.50 46 46 SURFA( DRILL RGRP T Make up a stand of 5"drill pipe to clean out ice in the condcutor. Pump @ 400 gpm w/300 psi.Attempt to test mud line and kelly hose to 3500 psi, again the actuated IBOP valve would not close. Stand back stand of 5"HWDP. Blow down the top drive. Hammer up connection on kelly hose.Steam IBOP.Change out broken sight glass on air dryer cannister on the top drive. Page 3 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 46 46 SURFA( DRILL PRTS IP Make up lift sub,then test mud line and automatic!BOP to 3500 psi-no leaks. Break off lift sub, blow down the top drive. Make up a stand of 5" HWDP,prepare to clean out ice from the conductor. 02/26/2012 Clean out ice in the conductor f/52'to 110' Pull up to 42', PJSM,continue to MU BHA#1 to 96', Pre spud meeting, PJSM on RU gyro equip, RU sheave in the derrick,drill f/110'to bottom of conductor @ 116', continue drilling f/116'to 189', KOP @ 189', continue drilling f/189'to 648'w/gyro surveys, Rig down gyro euip,Continue to directional drill w/MWD surveys f/648'to 1388'. 00:00 00:30 0.50 46 110 SURFA( DRILL REAM P Clean out ice in the conductor f/52' to 110'. Pumping 400 gpm w/320 psi, rotate 30 rpm w/3.5k ft lbs of torque. 00:30 01:00 0.50 110 42 SURFA( DRILL TRIP P Pull out of the hole f/110'to 42', break top drive, blow down. Break crossover. 01:00 01:15 0.25 42 42 SURFA( DRILL SFTY P Pre job safety meeting on picking up BHA. 01:15 02:45 1.50 42 96 SURFA( DRILL PULD P Continue to MU BHA#1: Make up NM stab,telescope, orient to motor, MU UBHO,orient, MU NM stab, NM crossover to 96' 02:45 03:00 0.25 96 96 SURFA( DRILL SFTY P Pre Spud meetingw/drilling crew and support crew. 03:00 03:15 0.25 96 96 SURFA( DRILL SFTY P Pre job safety meeting w/Halliburton Gyro hands. 03:15 03:30 0.25 96 96 SURFA( DRILL RURD P Hang Gyro sheave in the derrick. 03:30 03:45 0.25 96 96 SURFA( DRILL TRIP P Make a top drive connection w/stand of NM flex drill collars. 03:45 04:00 0.25 96 116 SURFA( DRILL REAM P Clean out ice in the conductor f/110' to bottom of conductor @ 116'. 04:00 12:00 8.00 116 612 SURFA( DRILL DDRL P pud 13-1/2"hole w/1.83 deg bend mtr f/116'to 612'(607'TVD).Gyro survey every stand. ADT-3.33 hrs ART 1.71 hrs AST 1.62 hrs Footage-496' Total hrs on bit 3.33hrs WOB 10/20 k RPM 30/40 GPM 400-600 @ 320-1060 psi String wt. PU 105 SO 100 ROT 105 Torque on/off btm.- 7/4.5 k ft/lbs KOP 189'@ 0440 am 2/26/2012. Jar#1621-0167: 3.33 hrs 12:00 12:45 0.75 612 648 SURFA( DRILL DDRL P Continue to directional drill 13-1/2" hole f/612'to 648'w/Gyro surveys. ADT-.5 hrs ART.17 hrs AST.33 hrs Footage-36' Total hrs on bit 3.83 hrs WOB 10/20 k RPM 30/40 GPM 400-600 @ 320-1060 psi String wt. PU 105 SO 100 ROT 105 Torque on/off btm.- 7/4.5 k ft/lbs Jar#1621-0167: 3.83 hrs Page 4 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:45 1.00 648 648 SURFA( DRILL RURD P Rig down Halliburton gyro tools. 13:45 18:00 4.25 648 957 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/648' to 957'w/MWD surveys. ADT-3.17 hrs ART.92 hrs AST 2.25 hrs Footage-309' Total hrs on bit 7hrs WOB 10/20 k RPM 30/40 GPM 400-600 @ 320-1060 psi String wt. PU 105 SO 100 ROT 105 Torque on/off btm.- 7/4.5 k ft/lbs Jar#1621-0167: 7 hrs 18:00 00:00 6.00 957 1,388 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/957' to 1388'(1343'TVD)w/MWD surveys. ADT-3.79 hrs ART 1.13 hrs AST 2.66 hrs Footage-431' Total hrs on bit 10.79 hrs(440'+/-rot, 819'+/- sliding) WOB 10/20 k RPM 40 GPM 600 @ 1100 psi String wt. PU 110 SO 118 ROT 120 Torque on/off btm.- 8/6 k ft/lbs Jar#1621-0167: 10.79 hrs 02/27/2012 Continue to directional drill w/MWD surveys f/1388'to 2995'(2230'TVD). 00:00 12:00 12.00 1,388 2,308 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/1388' to 2308'(1961'TVD)w/MWD surveys. ADT-4.86 hrs ART 2.03 hrs AST 2.83 hrs Footage-920' Total hrs on bit 15.65 hrs WOB 10/30 k RPM 40 GPM 600-700 @ 1100-1650 psi String wt. PU 128 SO 122 ROT 125 Torque on/off btm.- 10.5/7.5 k ft/lbs Jar#1621-0167: 15.65 hrs 12:00 00:00 12.00 2,308 2,995 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/2308' to 2995'(2230'TVD)w/MWD surveys. ADT-8.01 hrs ART 6.7 hrs AST 1.31 hrs Footage-687' Total hrs on bit 23.66 hrs WOB 10/30 k RPM 40 GPM 600-700 @ 1100-2000 psi String wt. PU 130 SO 120 ROT 124 Torque on/off btm.- 10.5/8 k ft/lbs Jar#1621-0167: 23.66 hrs 02/28/2012 Continue to directional drill w/MWD surveys f/2995'to 3657'(2486.69'TVD).CBUx3-BR-set back 3 stands, back ream f/3373'to 2431'. Page 5 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 2,995 3,196 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/2995' to 3196'(2303'TVD)w/MWD surveys. ADT-2.44 hrs ART 2.12 hrs AST .32 hrs Footage-201' Total hrs on bit 26.10 hrs WOB 15/30 k RPM 40 GPM 750 @2130 psi String wt. PU 130 SO 120 ROT 124 Torque on/off btm.- 10/8.5 k ft/lbs Jar#1621-0167: 26.10 hrs 03:30 04:30 1.00 3,196 3,196 SURFA( RIGMN?RGRP T Stand back a stand.Trouble shoot electrical problem w/the top drive blower motor. 04:30 11:30 7.00 3,196 3,351 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/3196' to 3351'(2367'TVD)w/MWD surveys. ADT-5.51 hrs ART 4.09 hrs AST 1.42 hrs Footage-155' Total hrs on bit 31.61 hrs WOB 10/30 k RPM 40 GPM 750 @2100 psi String wt. PU 130 SO 122 ROT 125 Torque on/off btm.- 10.5/9 k ft/lbs Jar#1621-0167: 31.61 hrs 11:30 12:00 0.50 3,351 3,351 SURFA( DRILL SVRG P Service rig while change-out TD blower motor breaker,circulate, GPM 750 @ 2130 psi String wt. PU 130 SO 125 12:00 18:45 6.75 3,351 3,657 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/3351' to 3657'TD-(2486.69'TVD)w/MWD surveys. ADT-5.04 hrs ART 4.91 hrs AST .13 hrs Footage-306' Total hrs on bit 36.65 hrs-Total Sliding time 12.87 hrs--Total Rotating time 23.78 hrs. WOB 15/30 k RPM 40 GPM 750 @ 2200 psi String wt. PU 135 SO 127 ROT 126 Torque on/off btm.- 10/9 k ft/lbs Jar#1621-0167: 36.65 hrs 18:45 19:00 0.25 3,657 3,657 SURFA( DRILL SRVY P Obtain final survey. 19:00 21:00 2.00 3,657 3,373 SURFA( DRILL CIRC P Circulate bottomns up while setting back a stand every 1/2 hr.Set back 3 stands f/3657'to 3373'. Mud weight 9.8 ppg. Pumping 750 gpm w/ 2030-1900 psi. Rot 40-50 rpm w/ 8.5k ft lbs of torque. 21:00 00:00 3.00 3,373 2,431 SURFA( DRILL REAM P Backream out f/3373'to 2431'. Pumping 750 gpm w/initial 1900 psi, final 1770 psi. Rotate 40-50 rpm w/ 8.5k ft lbs of torque. One tight spot @ 2705'while backreaming. Page 6of72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/29/2012 24 hr Summary Continue to back ream f/2431'to 760', RIH to 833', monitor well-static losses.5 bph, B/D top drive,tag up w/ 35k @ 850',working w/pumps and rotary f/850'to 1769',BD top drive,trip in on elevators f/1769'to 3657'(no fill), PU a single,drill 4'f/3657'to 3661'.Circ&condition mud and hole f/10-3/4"casing(Increase gels, increase MW f/9.8 to 10 ppg),setting back a stand every'1/2 hr f/3661'to 3185', monitor well, BD top drive POOH on elevators f/3185'to 2995'. 00:00 02:30 2.50 2,431 1,486 SURFA( DRILL REAM P Backream out f/2431'to 1486'. Pumping 750 gpm w/initial 1770 psi, final 1700 psi. Rotate 40-50 rpm w/ 8.5k ft lbs of torque. Pulling speed 10'/min.Started seeing more cuttings at the shakers at about 1700'. 02:30 03:15 0.75 1,486 1,260 SURFA( DRILL REAM P Backream out f/1486'to 1260'. Slowed pump rate to 650 gpm w/ initial 1270 psi,final 1100 psi. Rotate 40-50 rpm w/7.5k ft lbs of torque. Pulling speed '8'min. 03:15 05:15 2.00 1,260 760 SURFA( DRILL REAM P Backream out f/1260'to 760'. Pumping 550 gpm w/initial 850 psi, final 760 psi. Rotate 40-50 rpm w/ 7.5k ft lbs of torque. Pulling speed 1260'to 1165'@ 5'/min. Then pulled @ 8-10'/min. Pulled last stand @ 3 bpm. Hole never cleaned up. 05:15 05:45 0.50 760 833 SURFA( DRILL TRIP P Orient to hi-side. Blow down top drive,trip in f/760'to 833'. Monitor well-static loss rate of'.5bph. 05:45 06:00 0.25 833 850 SURFA( DRILL TRIP P Trip in the hole on elevators f/833'to 850'.Tagged up hard @ 850',set down 35k. PU wt 120k,So wt 115k. 06:00 06:15 0.25 850 833 SURFA( DRILL TRIP P Orient toolface to 30L,pumping 105 gpm w/160 psi,then try to ream/work through-no go.Try slow rpm-no go. 06:15 06:45 0.50 833 833 SURFA( DRILL OWFF P Rack stand back and blow down top drive 06:45 07:00 0.25 833 925 SURFA( DRILL REAM P Orient TF 35L,slide through obstruction at 850'with 500 gpm, 790 psi. String bouncing while on obstruction.Got through,turned pumps off, RIH,stacked out at 870', worked/reamed through and wash to stand down at 925'. 07:00 07:45 0.75 925 925 SURFA( DRILL REAM P Backream full stand slowly to ream tight spots.Saw a lot of sand and pea gravel over shakers with some wood chips.Orient TF, run in stand w/o pump,took weight at 901'. Resume pump at 500 gpm, 830 psi and ream through with 50 rpm 6K torque. 07:45 08:30 0.75 925 925 SURFA( DRILL REAM P Backream full stand again slowly to clean up tight spots and cuttings. Still seeing a lot of sand/gravel. Orient TF, run in, still see tight spot at 901'but better, ream once more then looked good with out pump. Page 7 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 925 1,112 SURFA( DRILL REAM P Work/ream tight spots from 925'to 1112', rotating through tight spots and pushing through quickly as possible to avoid sidetracking. Backreaming each stand slowly to clean up tight spots and cuttings. Still seeing a lot of sand/gravel. 09:15 12:00 2.75 1,112 1,112 SURFA( DRILL RGRP T Ball mill cuttings tank overloaded with solids and was unable to process due to tank suctions plugging.Circulate slowly while ball mill worked issues.200 gpm,290 psi. 12:00 15:30 3.50 1,112 1,769 SURFA( DRILL REAM P Ream f/1112'to 1769', pumping 450 gpm w/800 gpm, rotate 50 rpm w/ 8-10k ft lbs of torque. Back ream each stand w/500 gpm w/880 psi, rotate 50 rpm w/9-10k ft lbs of torque.After each back ream, RIH with no pumps or rotary.Work through various tight spots. 15:30 15:45 0.25 1,769 1,769 SURFA( DRILL OTHR P Blow down the top drive. 15:45 18:15 2.50 1,769 3,657 SURFA( DRILL TRIP P Trip in the hole on elevators f/1769' to 3657'. Pick up a single. 18:15 18:30 0.25 3,657 3,661 SURFA( DRILL DDRL P Continue to drill 13-1/2"hole f/3657' to 3661'TD-(24888'ND)w/MWD surveys. ADT-.08 hrs ART.08 hrs AST 0 hrs Footage-4' Total hrs on bit 36.73 hrs-Total Sliding time 12.87 hrs--Total Rotating time 23.86 hrs. WOB 15 k RPM 50 GPM 600 @ 1400 psi String wt. PU 135 SO 127 ROT 126 Torque on/off btm.- 10/9 k ft/lbs Jar#1621-0167: 36.73 hrs 18:30 19:15 0.75 3,661 3,661 SURFA( DRILL CIRC P Circulate and condition mud, pumping 750 gpm w/1970 psi, rotate 50 rpm w/9k ft lbs of torque.Work 68'f/3661'to 3593'. 19:15 19:30 0.25 3,567 3,567 SURFA( DRILL PULD P Lay down single. 19:30 23:00 3.50 3,567 3,185 SURFA( DRILL CIRC P Circulate and condition mud: Set back a stand every'1/2 hr from 3567' to 3185'. Pumping 750 gpm w/1970 psi,final circ pressure 2020 psi. Perform a 275 bbl dilution,then weight up f/9.8 ppg to 10 ppg, increase gel f/30ppb to 40 ppb. 23:00 23:15 0.25 3,185 3,185 SURFA( DRILL OTHR P Monitor well-static, blow down the top drive. 23:15 00:00 0.75 3,185 SURFA( DRILL TRIP P Pull out of the hole w/BHA#1 f/ 3185'to 2995'on elevators.Tight spot worked out @ 3093'. Pulled 45k over. PU wt 135k, SOW 115k. Page 8 of 72 Time Logs Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/01/2012 24 hr Summary Continue to POOH w/13-1/2"BHA on elevators f/2995'to 2026'(pulled 45k over),Work 2146'to 1958' several times w/and w/o pumps and rotary,finally decide to back ream f/2147'to 650', POOH on elevators f/ 650'to 190', lay down Schlumberger BHA#1,clean floor, Rig up then run 10-3/4"45 ppf L-80 BTC-m casing to 1750'. 00:00 01:00 1.00 2,995 2,026 SURFA( DRILL TRIP P Continue to POOH w/13-1/2"BHA on elevators f/2995'to 2026'(pulled 45k over). Wiped out a tight spot @ 3093'-35k over pull,a little overpull @ 3089'to 2995'. PU wt 140-145k, SO wt 115k. 01:00 01:30 0.50 2,026 2,146 SURFA( DRILL TRIP P Run in the hole f/2036'to 2146' (115K SOW), POOH to 2124'-pulled tight,work till no drag, POOH f/2053' to 1958',then slack off,took weight _45k @ 2040'. RIH f/2053'to 2146'. 01:30 02:30 1.00 2,146 2,147 SURFA( DRILL REAM P Make a top drive connection, Pick up to 2120', pump out w/500 gpm w/ 940 psi, rotate 50 rpm w/10.5k ft lbs of torque.Circulate 500 bbls. SO wt 115k. 02:30 02:45 0.25 2,147 2,053 SURFA( DRILL TRIP P POOH on elevators f/2147'to 2053'. PU wt 135-140k. Blow down the top drive. 02:45 03:00 0.25 2,053 2,053 SURFA( DRILL TRIP P Attempt to pull stand#15 f/2053'w/ no pump. Pulled 45k over @ 2050'. 03:00 03:30 0.50 2,053 2,053 SURFA( DRILL TRIP P Pump 500 gpm w/920 psi. Pull w/ pumps f/2053'to 1958'.Shut down pumps,slacked off,took weight @ 1985'. Pumped out f/2053'to 1958'. Shut down pumps,took 45k weight @ 2026',2046',2039'. 03:30 05:00 1.50 2,053 2,053 SURFA( DRILL TRIP P Blow down the top drive.Trip in the hole w/stand#16 f/2053'to 2147'. Back ream and clean up hole f/2147' to 2053'. POOH f/2147'to 2053'- OK,Attempt to pull stand#15 f/ _2053'to 1958',tight @ 2001'. 05:00 08:00 3.00 2,053 650 SURFA( DRILL REAM P Decision to back ream f/2053'to 650'. Pumping initially 600 gpm w/ 1250 psi then 500 gpm w/920 psi. 08:00 09:00 1.00 650 190 SURFA( DRILL TRIP P Pull out of the hole f/650'to 190'. 09:00 12:00 3.00 190 0 SURFA( DRILL PULD P Lay down Schlumberger BHA#1 f/ 190'. 12:00 13:00 1.00 0 0 SURFA( DRILL PULD P Clear and clean rig floor. / 13:00 13:15 0.25 0 0 SURFA( CASING SFTY P PJSM on rigging up to run casing. 13:15 16:15 3.00 0 0 SURFA(CASING RURD P RU to run 10 3/4"45.5 ppf L-80 BTCM casing. 16:15 16:45 0.50 0 0 SURFA(CASING SFTY P PJSM on running casing with all hands. 16:45 20:15 3.50 0 1,330 SURFA(CASING RNCS P RIH with 10 3/4"45.5 ppf L-80 BTCM casing to 1330', began seeing some drag. Page 9of72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 20:30 0.25 1,330 1,330 SURFA(ICASING CIRC P Circulate to ensure shoe clear and get some fresh mud behind pipe, circulate 54 bbls total at 4 bpm,220 psi. 125K up, 112K down. 20:30 21:15 0.75 1,330 1,650 SURFA( CASING RNCS P Continue RIH with 10 3/4"45.5 ppf L-80 BTCM casing to 1650',taking weight. 21:15 00:00 2.75 1,630 1,750 SURFA( CASING RNCS P Wash mainly/work casing down from 1630'to 1750',with 4 bpm,220 psi increasing to 6 bpm 320 psi, 150K up, 110K down. 03/02/2012 Finish running 10-3/4"45.5 ppf L-80 BTC-m surface casing f/1750'to 3650.35'(Circ in the hole), MU Dowell cement head, circ and condition mud, PJSM, perform surface cement job w/62 bbls of cement returned to surface(142 sx,yield 2.45 cuft/sx)(100%returns). Bumped plug, checked floats-OK, R/D cement head, L/D landing joint, nipple down surface riser and adapter. 00:00 03:00 3.00 1,750 1,837 SURFA(CASING RNCS P Working casing down while circulating at 4 bpm at 220 psi to 8 bpm at 500 psi.from 1750'to 1837'. 165K up, 120K down. 03:00 06:15 3.25 1,837 1,963 SURFA(CASING RNCS P Work casing down more aggressively from 1837'to 1963'while circulating at 8 bpm 500 psi. 175K up, 125K down 06:15 11:45 5.50 1,963 3,611 SURFA( CASING RNCS P Wash casing down with 10-25K drag and work as needed from 1963'to 3611'. Reduced flow rate from 8 bpm to 6 bpm at 400 psi. 180K up, 130K _ down 11:45 12:45 1.00 3,611 3,650 SURFA(CASING RNCS P MU Hanger/landing joint and land casing at 3650'. RD Franks tool, Blow down top drive, MU Cement head. 12:45 15:15 2.50 3,650 3,650 SURFA(CEMEN-CIRC P Circulate and condition mud.Staging pump rate up to 7 bpm 440 psi. 215K up, 135K down. Casing collar hanging up on conductor 2'off bottom,stayed above this while circ and condition. Rig up Dowell cement head, connect lines. Circulate and condition mud and hole for cement job. Reciprocate pipe f/3650'to 3637'(13'). Initial pump rate 7 bpm w/ 440 psi,23%Totco flow out.Total of 1050 bbls pumped. Final mud properties: MW 9.9 ppg, PV/YP in 20/22, 72 funnel vis. Held PJSM f/cementing while circulating. Cont to circ&cond mud and hole for cement job. Page 10 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T CommentCC 15:15 18:45 3.50 3,650 3,650 SURFA( CEMEN-CMNT P Rig mixed&pump 121 bbls of 9.9 fir" ppg mud w/nut plug marker(5ppb), S followed w/33 bbls of viscosified C, p biozan water w/nut plug(5ppb). Pump @ 7 bpm w/290 psi. PU wt 215k,SO wt 135k. Dowell pumped 3 bbls water and press test to 2500 psi. Drop bottom plug. Dowell pump 44 bbls of MudPush II (10.5 ppg). Pump 4 bpm w/final press of 175 psi. Dowell mixed and pumped a total of 485 bbls(1111 sx1 of 10.7 ppg ArcticSet Lite cement(Yield 2.45 cuft/sx)(11.53 gal/sx mix water).Avg pump rate of 7 bpm w/ initial press of 280 and final of 123 psi. Dowell mixed&pumped 53.3 bbls(258 sx)of 15.8 ppg class"G" tail cement(Yield 1.16 cuft/sx)(5.1 gal/sx mix water).Avg pumping rate of 4.8 bpm w/final of 98 psi. Drop top plug. Dowell displace and wash up through the tub, pumping 20 bbls of water. Reciprocate pipe f/3650'to 3637'(13'). Rig displaced cement w/ 9.9 ppg mud. Pumping the first 310 bbls @ 8 bpm w/370 psi initial and 790 psi final,then slowed rate for the last 14 bbls to 2 bpm w/480 psi. Bumped plugs w/500 psi over--1100 psi @ 18:45 hrs 3/2/2012, held ft 5 minutes. Note: Reciprocated pipe f/3650'to 3637'(13').while displacing cement, set on hanger 173 bbls prior to ✓/ bumping plug.-Had 62 bbls(142 sx) of good 10.7 ppg cement to surface. Full returns throughout job._SO wt 125k. PU wt 240k. Note:Cement in place @ 18:47 hrs 3-2-2012. Bled off pressure to check floats,floats held. PJSM,rig down cement and casing equip. 18:45 19:00 0.25 3,650 3,650 SURFA(CEMEN-OTHR P Bleed off pressure.Check floats-OK. 19:00 21:15 2.25 3,650 0 SURFA(CEMEN-RURD P Flush riser w/black water. Blow down lines. Rig down cementing head. Lay down the 10-3/4" landing joint. 21:15 21:30 0.25 0 0 SURFA(WHDBO SFTY P Pre job safety meeting on nippling down riser and FMC adapter. 21:30 00:00 2.50 0 0 SURFA(WHDBO NUND P Lay down mouse hole. Nipple down surface riser. Nipple down FMC 16" surface adapter. Page 11 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/03/2012 24 hr Summary Nipple up FMC wellhead,test metal to metal seal to 1000 psi f/10 minutes, NU 13-5/8"BOPE, RU to test, attempt to test-FMC wellhead SSSV ports leaking,fix same.Test BOPE,witness of test waived by AOGCC inspector Jeff Jones. Replaced HCR choke line valve and tested same. R/D test equip, install wear bushing, PU drilling tools to floor, PJSM, PU stand back 27 stands of 5"dp. 00:00 00:15 0.25 0 SURFA(WHDBO NUND P Nipple up FMC wellhead. 00:15 00:30 0.25 SURFA(WHDBO PRTS P Test metal to metal seal on top of the 10-3/4"casing hanger to 1000 psi f/10 minutes-good. 00:30 03:00 2.50 SURFA(WHDBO NUND P Nipple up 13-5/8"BOP stack and riser. 03:00 04:00 1.00 SURFA(WHDBO RURD P Rig up to test BOPE. 04:00 04:45 0.75 SURFA(WHDBO OTHR P Fill hole w/water,work air from system,attempt to test BOPE. 04:45 06:30 1.75 SURFA(WHDBO PRTS T FMC wellhead leaking from both outlets for the sub surface safety valve with 3000 psi. Bleed off pressure,attempt to tighten gland nut,Attempt again, leaking. FMC rep removed both gland nuts and fittings, teflon tape the plugs, re-install gland nuts,tighten.Test to 3500 psi-good. 06:30 07:45 1.25 SURFA(WHDBO RURD P Working air out of sytem,trying to test annular. 07:45 08:45 1.00 SURFA(WHDBO BOPE P Initial BOPE test,witness waived by AOGCC inspector Jeff Jones:Test annular to 250 psi low and 2500 psi high. Hold each test 5 minutes, n charted test.Tested to choke V manifold valves 1, 5, 14, 15&16. � Tested kill line HCR.Test top pipe rams(3-1/2"x 6"VBR)to 250 psi low and 3500 psi high(Tested same valves in the choke manifold to 3500 psi and Kill line HCR).Tested upper IBOP(Auto valve),and manual IBOP on the top drive to 250 psi low and 3500 psi high. Hold each test 5 minutes. Charted tests. 08:45 09:00 0.25 SURFA(WHDBO OTHR P Blow down the top drive and choke line. 09:00 09:30 0.50 SURFA( RIGMNT SFTY P Pre job safety meeting on: Continuing to test BOPE and replacing the hydraulic controlled valve on choke line(external leak from stem packing). 09:30 10:15 0.75 SURFA(WHDBO BOPE P Continue BOPE test:Test the floor full open safety valve and floor dart valve to 250 psi low and 3500 psi high. Hold each test f/5 minutes, chart test. SIM Ops: Rig up scaffolding to change out HCR valve on the choke side. Remove choke hose and HCR valve. 10:15 11:00 0.75 SURFA( DRILL RURD P Install bales on the top drive, install elevators. Page 12 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 SURFA( DRILL SFTY P Pre job safety meeting on picking up BHA componets. 11:30 12:00 0.50 SURFA( DRILL PULD P Pick up drilling BHA componets to the rig floor. 12:00 12:15 0.25 SURFA( DRILL SFTY P Pre job safety meeting,crew change. 12:15 13:45 1.50 SURFA( RIGMNT RGRP T Install a different HCR choke line valve. Make up choke line hose. 13:45 14:30 0.75 SURFA(WHDBO RURD T Rig up to continue to test BOPE. 14:30 19:15 4.75 SURFA(WHDBO BOPE P Continue to test BOPE:Test top pipe rams(3-1/2"x 6"),with choke line valves 2,10,13 and HCR on kill line,test choke valves 6,8,9&HCR kill line,choke valve 3 and HCR kill line, HCR choke line and Demco valve(mud line)on kill line side,test manual kill and choke line valve. Test lower pipe rams w/5"test joint. Test blind rams w/HCR kill closed and choke valve#4.All tests held f/ 5 minutes. Charted tests. Performed Koomey test: Initial pressure 3000 psi,after closure 1450 psi,28 seconds f/200 psi build up, full charge in 190 seconds. Four nitrogen bottles, average pressure 2000 psi. Electrician tested gas alarms. Pumped through the auto choke, and then the manual choke, 1 bpm,choked flow to increase pressure to 1100 psi for each. 19:15 20:00 0.75 SURFA(WHDBO RURD P Blow down lines. Pull FMC test plug. Install FMC wear bushing(OD 10.91', ID 10"). 20:00 20:30 0.50 SURFA( DRILL PULD P Lay down the test joint. Pick up drilling tools from the beaver slide. 20:30 00:00 3.50 0 0 SURFA( DRILL PULD P Pick up&stand back 27 stands of 5"drill pipe(62 stands in the derrick @ midnight). 03/04/2012 PJSM, PU/stand back 5"drill pipe in the derrick, PJSM, PU/MU BHA#2: (9-7/8"steerable),shallow test, ✓ slip and cut drill line, continue to PU 5"dp-RIH f/pipe shed to 2248', MU 9-7/8"ghost reamer, con't w/5"dp, rotate thru TAM port collar @ 790', con't RIH w/5"dp to 952',test casing to 3500 psi-ok,con't RIH w/5"f/ shed to 3041'(ghost reamer took 4k weight @ TAM port collar, PU, Rotate through Port collar @ 790'w/ ghost reamer to 3068',test casing to 3050 psi-ok, con't to PU/MU/RIH w/5"dp f/3068'to 3320',Trip in f/ derrick w/5"to 3414',wash/ream f/3414'to tag cement @ 3570',CBU,stand back a stand to 3508', RU then test 10-3/4"45.5 ppf L-80 BTC-m casing to 3650 psi f/30 minutes(chart test)-good, RD test equip, Ream f/ 3508'to top of cement @ 3570',drill cement to wiper rubbers @ 3574'. Drill on 10-3/4"csg wiper rubbers @ 3574'. 00:00 00:15 0.25 SURFA('DRILL SFTY P Pre job safety meeting on picking up /standing back 5"drill pipe. 00:15 05:00 4.75 SURFA( DRILL PULD P Pick up&stand back 51 stands of 5"drill pipe(113 stands in the derrick @ 0500 hrs). 05:00 05:30 0.50 SURFA( RIGMNT SVRG P Service rig. Page 13 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:00 2.50 SURFA( DRILL PULD P Pick up&stand back 23 stands of 5"drill pipe(136 stands in the derrick). 08:00 08:15 0.25 SURFA( DRILL SFTY P Pre job safety meeting on picking up /make up BHA#2. 08:15 09:45 1.50 0 213 SURFA( DRILL PULD P Pick up/make up BHA#2: 9-7/8" Hycolog SKH516M-B2C(ser# A154696), PowerDrive Xceed 675 (rotary steerable), EcoScope (MWD/LWD) (G R/RES/DENS/NEUT/ACAL/PWD), Telescope(generator), NM Stab, sonicVISION(acoustic wave generator), NM stab, (3)NM flex collars,saver sub. Pick up to install nuke sources. 09:45 10:00 0.25 213 213 SURFA( DRILL SFTY P Pre job safety meeting on handling nuke sources @ 213'. 10:00 10:15 0.25 213 213 SURFA( DRILL OTHR P Load nuke sources. 10:15 10:45 0.50 213 674 SURFA( DRILL TRIP P Continue with BHA#2: RIH w/(3) NM flex collars,saver sub to 213', Make up one 5"HWDP,6-1/4"DNT Weatherford jars, 13 jts 5"HWDP to 674'. 10:45 11:15 0.50 674 674 SURFA( DRILL DHEQ P Make a top drive connection w/the top drive.Shallow test MWD tool w/ 500 gpm w/820 psi. 11:15 11:30 0.25 674 674 SURFA( DRILL OTHR P Blow down the top drive. 11:30 11:45 0.25 674 674 SURFA( RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line. 11:45 12:00 0.25 674 674 SURFA( RIGMNTSLPC P Slip and cut 1-3/8"drilling line. 12:00 12:15 0.25 674 674 SURFA( RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line.Crew change. 12:15 13:30 1.25 674 674 SURFA( RIGMNT SLPC P Slip and cut 75'of 1-3/8"drilling line. Check Totco EDMS. Check brakes and crown device. Service rig. 13:30 14:00 0.50 674 764 SURFA( DRILL PULD P Continue to PU/MU/RIH w/ 5"drill pipe f/the pipe shed to f/674'to 764' 14:00 14:30 0.50 764 824 SURFA( DRILL REAM P Make a top drive connection on next joint above the table,then rotate bit ✓ past the TAM port collar @ 790.75'. Rotate to 824'. Rotate 15 rpm w/4k ft lbs of torque f/764'to 824'.Took weight @ 794'. 14:30 14:45 0.25 824 952 SURFA( DRILL TRIP P Continue to PU/MU/RIH w/ 5"drill pipe f/the pipe shed to f/824'to 952' 14:45 15:30 0.75 952 952 SURFA( DRILL DHEQ P Fill pipe. Line up to test the casing& TAM port collar to 3500 psi(59 strokes).Tam Port Collar is closed. Bled off pressure. Blow down kill line and top drive. �.._..__...._ _ Page 14 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:45 3.25 824 3,041 SURFA( DRILL PULD P Continue to PU/MU/RIH w/5"drill pipe from the pipe shed f/952'to 2248'.Then PU/MU Weatherford 9-7/8"Ghost reamer(ser#274543) to 2255',continue 5"dp f/shed to 3041'(Ghost reamer @ Tam port collar-790.75')(took 4k weight). 18:45 19:30 0.75 3,041 3,068 SURFA( DRILL REAM P Pick up 4'to 3037', rotate down w/ 40 rpm 11k ft lbs of torque f/3041'to 3068'.Took a little weight @ 3041' Ghost reamer @ Tam port collar) (Ream w/1-2k WOB).Circulate to test MWD, pumping 500 gpm w/ 1090 psi-OK. 19:30 20:00 0.50 3,068 3,068 SURFA( DRILL DHEQ P Test casigand TAM port collar @ ✓ _790.75'to 3050 psi-( 4 strokes)LOK.. Blow down kill line and top drive. 20:00 20:30 0.50 3,068 3,320 SURFA( DRILL PULD P Continue to PU/MU/RIH w/5"drill pipe from the pipe shed f/3068'to 3320'. 20:30 20:45 0.25 3,320 3,314 SURFA( DRILL TRIP P Trip in the hole from the derrick f/ 3320'to 3414'. 20:45 21:15 0.50 3,314 3,570 SURFA(CEMEN-REAM P Wash/Ream in the hole f/3414'to 3570', pumping 600 gpm w/1600 psi, rotate 50 rpm w/12k ft lbs of torque. 21:15 21:30 0.25 3,570 3,570 SURFA( CEMEN-CIRCP Tagged cement @3570'. Circulate bottom's up, pumping 750 gpm w/ 2300 psi, rotate 50 rpm w/12k ft lbs of torque. 21:30 21:45 0.25 3,570 3,508 SURFA(CEMEN-TRIP P Stand back a stand f/3570'to 3508'. 21:45 22:00 0.25 3,508 3,508 SURFA(CEMEN"OTHR P Blow down the top drive. 22:00 22:15 0.25 3,508 3,508 SURFA(CEMEN"RURD P Rig up to test the 10-3/4"45.5 ppf L-80 BTC-m casing. PU wt 140k. 22:15 23:00 0.75 3,508 3,508 SURFA(CEMEN"DHEQ P Test the 10-3/4"45.5 ppf L-80 BTC-m casing to 3650 psi f/30 minutes. Charted test. 23:00 23:30 0.50 3,508 3,508 SURFA(CEMEN"RURD P Bleed off pressure. Rig down testing equipment. Blow down the kill line and top drive. 23:30 00:00 0.50 3,508 3,574 SURFA( CEMEN-COCF P Make a top drive connection,then ream f/3508'to 3570',drill cement f/ 3570'to tag wiper plugs above float collar.Tagged wiper rubbers @ 3573.59'. Rotate 50 rpm w/12.5k ft lbs of torque, pumping 600 gpm w/ 1560 psi. Drilling on wiper rubbers w/5k WOB. 03/05/2012 Drill on 10-3/4"csg wiper rubbers @ 3574', clean out cement f/shoe track&rat hole to 3661',drill 20'new hole to 3681', CBU, perform FIT to 18 ppg EMW,continue to drill 9-7/8"intermediate hole w/Schlumberger BHA#2(Rotary steerable)f/3681'to 4925'. Page 15 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:45 2.75 3,574 3,650 SURFA( CEMEN'DRLG P Drilling on wiper rubbers @ 3574', drill float collar @ 3574.59'to 3575.79'. Drilling cement to Rays Silver bullet shoe @ 3648.10'to 3650.35'. Drill w/5k WOB. Pumping 600 gpm w/1560 psi. Rotate 50 rpm w/12-12.5k ft lbs of torque. Ream out after drilling. 02:45 03:00 0.25 3,650 3,661 SURFA(CEMEN-DRLG P Clean out the rat hole from 3650'to 3661'. Drill w/5k WOB. Pumping 600 gpm w/1560 psi. Rotate 50 rpm w/ 12-12.5k ft lbs of torque. 03:00 03:15 0.25 3,661 3,661 SURFA(CEMEN-DRLG P Ream out rat hole and float shoe f/ 3661'to 3600'. Pumping 600 gpm w/ 1560 psi, roate 50 rpm w/12k ft lbs of torque. 03:15 03:45 0.50 3,661 3,681 SURFA(rCEMEN"DRLG P Drill 20'of 9-7/8"new hole f/3661'to 3681'.ADT.54 hrs. Drill w/8k WOB, pumping 650 gpm w/1780 psi. Rotate 80 rpm w/12k ft lbs of torque off bottom, 14k ft lbs on bottom. PU wt 152k,SO wt 120k, Rot wt 130k. 03:45 04:00 0.25 3,681 3,681 SURFA(CEMEN-CIRC P Circulate bottom's up. Reciprocate and rotate f/3681'to 3600'. Pumping 600 gpm w/1560 psi. Rotate 50 rpm w/12 k ft lbs of torque. 04:00 04:15 0.25 3,681 3,602 SURFA( CEMEN-TRIPP Stand back a stand f/3681'to 3602'. 04:15 04:45 0.50 3,602 3,602 SURFA( CEMEN"RURD P Rig up to test the formation. 04:45 05:00 0.25 3,602 3,602 SURFA( CEMEN-FIT P Perform formation integrity test. Mud weight 9.8 ppg, 10 sec gel=5, 10 min gel=30,30 min gel=38, PV/YP 17/10, Funnel vis 48.Apply 1060 psi surface pressure. Float shoe @ 3650.35'(2483'TVD),drilled to 3681' (2496'TVD). Formation integrity test to 18 ppg EMW. 05:00 05:15 0.25 3,602 3,602 INTRM1 CEMEN-RURD P Rig down testing equipment. 05:15 05:30 0.25 3,602 3,681 INTRM1 CEMEN-OTHR P Blow down the kill line. Make a top drive connection on stand. 05:30 12:00 6.50 3,681 4,091 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole w/ Schlumberger rotary steerable system f/3681'to 4091' (2653' TVD).ADT 3.87 hrs.Jar hrs 41.11. Drill w/5-15k WOB, pumping 650-750 gpm w/1380-1600 psi. Rotate 80-120 rpm w/12-12.5k ft lbs of torque off bottom, 12-13.5k ft lbs on bottom. PU wt 155k, SO wt 115k, Rot wt 130k. Note:Started pumping sweeps every third stand, alternating f/ weighted(11.6 ppg)to non weighted hi vis w/3ppb nut plug. Pumped Hi vis sweep w/3 ppb nut plug @ 3980'. Effective. �^ Page 16 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment I 12:00 18:30 6.50 4,091 4,665 INTRM1 DRILL 'DDRL P Drill 9-7/8"intermediate hole w/ Schlumberger rotary steerable system f/4091'to 4665' (2868' TVD).ADT 3.81 hrs.Total hrs on bit= 8.22,Jar hrs 44.92. Drill w/8-16k WOB, pumping 750 gpm w/ 1680-1800 psi. Rotate 110-130 rpm w/8-12k ft lbs of torque off bottom, 10-13.5k ft lbs on bottom. PU wt 136k, SO wt 135k, Rot wt 136k. Pumped weighted sweep w/3 ppb nut plug @ 4262', Hi vis sweep w/3 ppb nut plug @ 4545'. Effective. Started adding lubes to mud f/ vibration @'4200'. 1.5%(1%Drill zone&.5% 776). 18:30 19:00 0.50 4,665 4,665 INTRM1 DRILL DDRL P Rack back one stand,got off highline power, ran on Rig Gens#2 to change tap on highline transformer in order to get proper rig voltage(600v), got back on highline. 19:00 00:00 5.00 4,665 4,925 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole w/ Schlumberger rotary steerable system f/4665'to 4925' (2964' TVD).ADT 2.13 hrs.Total hrs on bit= 10.35,Jar hrs 47.05 Drill w/5-15k WOB, pumping 750 gpm w/ 1800-1850 psi. Rotate 120 rpm w/ 9.5-11.5k ft lbs of torque off bottom, 9.5-11.5k ft lbs on bottom. PU wt 145k, SO wt 128k, Rot wt 140k. 03/06/2012 Drilled 9 7/8"hole w/Schlumberger Power Drive rotary steerable system f/4925'to 6820' 00:00 12:00 12.00 4,925 5,870 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole w/ Schlumberger rotary steerable system f/4925'to 5870' (3313' TVD).ADT 7.54 hrs.Total hrs on bit= 17.89,Jar hrs 54.59 Drill w/15-20k WOB,pumping 750 gpm w/ 1830-2100 psi. Rotate 100-120 rpm w/8.5k ft lbs of torque off bottom, 10.5k ft lbs on bottom. PU wt 150k, SO wt 140k, Rot wt 144k. 12:00 00:00 12.00 5,870 6,820 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive rotary steerable system f/5870'to 6820'MD-3664'TVD ADT-8.04 hrs ECD-10.7 ppg Footage-950' WOB 12/20 k RPM 120 GPM 750 @ 2260 psi String wt. PU 158 SO 146 ROT 152 Torque on/off btm.-11.5/9.5 k ft/lbs 03/07/2012 Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/6820'to 8725' Page 17 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 6,820 7,704 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schumberger Power Drive RSS f/6820'to 7704' MD 3998'TVD ADT-7.59 hrs. ECD-10.65 ppg Footage-884' WOB-18/25 k RPM 120 GPM 750 @ 2030 psi String wt. PU 162 SO 150 ROT 157 Torque on/off btm.-11.5/9 k ft/lbs 12:00 00:00 12.00 7,704 8,725 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Shlumberger Power Drive RSS f/7704'to 8725' MD 4382'TVD ADT-7.32 hrs. ECD-10.56 ppg Footage-1021' WOB 18/20 k RPM 120 GPM 750 @ 2100 psi String wt. PU 182 SO 153 ROT 168 Torque on/off btm.- 15.5/12 k ft/lbs 03/08/2012 Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/ 8725'to 10,600' 00:00 12:00 12.00 8,725 9,700 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/8725'to 9700' MD 4750'TVD ADT-7.24 hrs ECD-10.57 ppg Footage-975' WOB 15/22 k RPM 120 GPM 750 @2110 psi String wt. PU 190 SO 160 ROT 175 Torque on/ioff btm.-15.5/12.5 k ft/lbs 12:00 00:00 12.00 9,700 10,600 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f 9700'to 10,600' MD 5086'TVD ADT-6.53 hrs ECD-10.52 ppg Footage-900' WOB 20/25 k RPM 120 GPM 750 @ 2190 psi String wt. PU 206 SO 161 ROT 184 ✓ Torque on/off btm.- 17/14 k ft/lbs 03/09/2012 Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/ 10,600'to 12,625' 00:00 12:00 12.00 10,600 11,606 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f 10,600'to 11,606' MD 5466'TVD ADT-7.09 hrs ECD-10.59 ppg Footage-1006' WOB 20/24 k RPM 120/140 GPM 750 @ 2210 psi String wt. PU 211 SO 165 ROT 185 Torque on/off btm.- 19.5/16 k ft/lbs Page 18 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 11,606 12,625 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f 11,606' to 12,625'MD 5845'TVD ADT-7.36 hrs ECD-10.60 ppg Footage-1019' WOB 20/25 k RPM 140 GPM 750 @ 2300 psi String wt. PU 225 SO 170 ROT 193 Torque on/off btm.- 20.5/167 k ft/lbs 03/10/2012 Drilled 9 7/8"hole w/ Schlumberger Power Drive RSS f/12,625'to 13,940' 00:00 12:00 12.00 12,625 13,421 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drvie RSS f/12,625'to 13,421' MD 6142'TVD ADT-7.02 hrs ECD-10.40 ppg Footage-796' WOB 20/22 k RPM 140 GPM 750 @ 2240 psi String wt. PU 235 SO 175 ROT 203 Torque on/off btm.-21.5/17.5 k ft/lbs. 12:00 13:15 1.25 13,421 13,421 INTRM1 DRILL OTHR T Trouble shoot MWD-Pumping 750 gpm @ 2300 psi 80 rpm @ 20 k torque(porosity data f/Ecoscope tool died)decision made to drill ahead w/o this data 13:15 00:00 10.75 13,421 13,940 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/13,421'to 13,940' MD 6212'TVD ADT-6.53 hrs ECD-11.25 ppg Footage-519' WOB 14/25 k RPM 100 GPM 750 @ 2850 psi String wt. PU 240 SO 170 ROT 195 Torque on/off btm.-24/19 k ft/lbs Note; Began adding mud products for drilling HRZ and bringing wt. up to 10.5 ppg-experiencing high torque- adding 776&Lo-Torque 03/11/2012 Drilled 9 7/8"hole w/ Schlumberger Power Drive RSS f/ 13,940'to 15,083' 00:00 08:45 8.75 13,940 14,442 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/13,940'to 14,442' MD 6457'TVD ADT-5.27 hrs ECD-11.25 ppg Footage-502' WOB 18/22 k RPM 120 GPM 750 @ 3120 psi String wt. PU 242 SO 167 ROT 200 Torque on/off btm.-23/17 k ft/lbs 08:45 09:30 0.75 14,442 14,442 INTRM1 DRILL RGRP T Lost power to shakers-rig electrician-troubleshoot and repair Page 19 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 14,442 14,519 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/14,442'to 14,519' MD 6491'TVD ADT-1.02 hrs ECD-11.25 ppg Footage-77' WOB 18/22 k RPM 120 GPM 750 @ 3120 psi String wt. PU 242 SO 167 ROT 200 Torque on/off btm.-23/17 k ft/lbs 12:00 00:00 12.00 14,519 15,083 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/14,519'to 15,083' MD 6683'TVD ADT-7.31 hrs. ECD-11.44 ppg Footage-564' WOB 15/25 k RPM 100/120 GPM 750 @ 3300 psi String wt. PU 265 SO 160 ROT 200 Torque on/off btm.- 25.5/18 k ft/lbs 03/12/2012 Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/15,083'to 15,613'-Circ 3 X btms up&wt. up to 11.0 ppg-BROOH to 14,613'(MADD pass f/15,107'to 14,679')-BROOH f/14,613'to 14,141' 00:00 12:00 12.00 15,083 15,554 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/15,083'to 15,554' MD 6847'TVD ADT-9.14 hrs. ECD-11.2 ppg Footage-471' WOB 10/12 k RPM 120 GPM 750 @ 3360 psi String wt. PU 282 SO 163 ROT 208 Torque on/off btm.- 28.2/21 k ft/lbs 12:00 13:00 1.00 15,554 15,613 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive RSS f/15,554'to 15,613' MD 6868'TVD ADT-.98 hrs. ECD-11.25 ppg Footage-59' WOB 8/12 k RPM 120 GPM 750 @ 3350 psi String wt. PU 310 SO 160 ROT 198 Torque on/off btm.-27.5/21 k ft/lbs 13:00 13:30 0.50 15,613 15,555 INTRM1 DRILL TRIP P Survey @ TD-POOH f/15,613'to 15,555' 13:30 17:30 4.00 15,555 15,460 INTRM1 DRILL CIRC P Circ 3 X btms up @ 750 gpm @ 3350 psi w/80 rpm's @ 21 k torque- weighting up f/10,.5 ppg to 11.0 ppg -Standing back 1 std DP every 30 mins f/15,555'to 15,460' 17:30 17:45 0.25 15,460 15,460 INTRM1 DRILL CIRC P Flow ck-well static-Obtain SPR's 17:45 22:45 5.00 15,460 14,613 INTRM1 DRILL TRIP P BROOH f/15,460'to 14,613'@ 675 gpm @ 3060 psi w/80 rpm's @ 21 k torque-MADD pass f/15,107'to 14,679' Page 20 of 72 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:45 23:00 0.25 14,613 14,613 INTRM1 DRILL TRIP P Blow down TD-Flow ck well static- Attempt to POOH on elevators f/ 14,613'-Pulled to 14,582'-Pulled 75 k over-unable to pull past 14,582' - RIH to 14,613' 23:00 00:00 1.00 14,613 14,141 INTRM1 DRILL TRIP P BROOH f/14,613'to 14,141'@ 750 gpm @ 3650 psi w/120 rpm's @ 21 k torque Note-BROOH as per Drilling Engineer 03/13/2012 BROOH f/14,141'to 13,668'-POOH on TT f/13,668'to 12263', Pump a dry job, POOH on elevators f/12263' to 10767',CBU, POOH on trip tank f/10850'to 10756', Backream f/10756'to 9255', CBUx2, POOH f/9255' to 8859', Backream f/8879'to 5296'@ midnight. 00:00 01:15 1.25 14,141 13,668 INTRM1 DRILL TRIP P BROOH f/14,141'to 13,668'@ 750 gpm w/120 rpm's @ 23 k torque 01:15 03:00 1.75 13,668 12,263 INTRM1 DRILL TRIP P Blow down TD-Flow ckl well static- POOH on TT f/13,668'to 12,263'- PU wt 275 SO wt 155 03:00 03:30 0.50 12,263 12,263 INTRM1 DRILL CIRC P Flow ck well static-Pumped dry job -Blow down TD 03:30 05:30 2.00 12,263 10,850 INTRMI DRILL TRIP P Cont. POOH on TT f/12,263'to 10,767' -PU wt 220 SO wt 150- Worked thru tight spot @ 10,925'- Pulling 35 k over-Worked tight spot @ 10,767'-pulling 75 k over-unable to work past-RIH to 10,850' 05:30 06:45 1.25 10,850 10,850 INTRM1 DRILL CIRC P Flow ck-well static-Circ btms up f/ 10,850'@ 600 gpm @ 2180 psi w/ 120 rpm's @ 17 k torque 06:45 07:00 0.25 10,850 10,756 INTRM1 DRILL TRIP P Flow ck-well static-Blow down TD- POOH on TT f/10,850'to 10,756'- PU wt 220 SO wt 150-Pulling tight @ 10,750'-worked pipe pulling 60 k over-RIH to 10,756' 07:00 10:45 3.75 10,756 9,255 INTRM1 DRILL TRIP P BROOH f/10.750'to 9255'@ 600 gpm @ 2170 psi w/120 rpm's w/ 18/20 k torque 10:45 12:15 1.50 9,255 9,255 INTRM1 DRILL CIRC P Circ 2 X btms up @ 9255'-690 gpm @ 2500 psi w/120 rpm's @ 18k torque 12:15 12:30 0.25 9,255 9,255 INTRM1 DRILL OWFF P Flow ck-well static-Blow down TD 12:30 13:00 0.50 9,255 8,879 INTRM1 DRILL TRIP P POOH on TT f/9255'to 8859'- pulling tight @ 8859'-Worked pipe pulling 65 k over-RIH to 8879' 13:00 00:00 11.00 8,879 5,296 INTRMI DRILL TRIP P BROOH f/8879'to 5296'. Pumping 670 gpm w/2240-2070 psi. Rotate 120 rpm's w/16-10.5k ft lbs of torque. Puling tight @ 8869', 8400',5718', 5661', 5622', 5540',5342'and 5297'. 03/14/2012 Continue to backream f/5296'to 3602', monitor well-static,CBU x2, pump a hi vis sweep, monitor well- static, POOH on trip tank f/3602'to 661', monitor well-static, pull out f/661'to 186', PJSM, remove nuke sources, lay down BHA, clear floor, RU tubing equipment, PJSM, MU/RIH w/mule shoe and 29 jts of 3-1/2" 9.3 ppf L-80 tbg+(2)x-o's to 913', RD tbg equipment, RIH w/cement stinger on 5"dp to 3646'. Page 21 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:15 7.25 5,296 3,602 INTRM1 DRILL TRIP P BROOH f/5296'to 3602'. Pumping 670-600 gpm w/2070-1590 psi. Rotate 120 rpm's w/10.5-10kk ft lbs of torque. 07:15 07:30 0.25 3,602 3,602 INTRM1 DRILL OWFF P Blow down the top drive.Observe well f/flow-static. 07:30 08:15 0.75 3,602 3,602 INTRM1 DRILL CIRC P Circulate two bottom's up. Pumping 600 gpm w/1450 psi, rotate 100 rpm w/8k ft lbs of torque. Pump a 35 bbl hi vis sweep. Not a lot of cuttings on bottom's up. 08:15 08:45 0.50 3,602 3,602 INTRM1 DRILL OWFF P Blow down the top drive.Observe well f/flow-static. 08:45 12:00 3.25 3,602 1,614 INTRM1 DRILL TRIP P Pull out of the hole on the trip tank f/ 3602'to 1614'. PU wt 125k, SO wt 125k. 12:00 14:00 2.00 1,614 661 INTRM1 DRILL TRIP P Pre job safety meeting. Continue to POOH on the trip tank f/1614'to 661'. 14:00 14:15 0.25 661 661 INTRM1 DRILL OWFF P Monitor well @ BHA-static. 14:15 15:00 0.75 661 186 INTRM1 DRILL TRIP P Continue to pull out of the hole f/661' to 186'. 15:00 15:15 0.25 186 186 INTRM1 DRILL SFTY P Pre job safety meeting on removing nuke sources. 15:15 15:30 0.25 186 186 INTRM1 DRILL OTHR P Remove sources. 15:30 18:00 2.50 186 0 INTRM1 DRILL PULD P Lay down Schlumberger BHA#2 (9-7/8"rotary steerable). 18:00 18:15 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting. 18:15 18:45 0.50 0 0 INTRM1 DRILL PULD P Clear rig floor. 18:45 19:00 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on rigging up 3-1/2"equipment f/cementing. 19:00 19:45 0.75 0 0 INTRM1 DRILL RURD P Rig up tubing equipment. 19:45 20:15 0.50 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on rigging up making up 29 joints of 3-1/2"EUE tubing for ceement stinger. 20:15 21:45 1.50 0 913 INTRM1 PLUG PULD P Make up a 3-1/2"mule shoe, 29 joints of 3-1/2"EUE 9.3 ppf L-80 tubing and two crossovers to 913'. 21:45 22:00 0.25 913 913 INTRM1 PLUG RURD P Rig down tubing running equipment. 22:00 00:00 2.00 913 3,646 INTRM1 PLUG TRIP P Run 3-1/2"cement sting on 5"drill pipe f/913'to 3646' 03/15/2012 Slip and cut drill line,con't RIH w/cement stinger on 5"DP f/3646'to 15,598'(installing Super Sliders)-Circ '`r) &condition mud for cmt plugs-PJSM, Dowell PT to 3k-ok, pump 37.5 bbls MP(12.5 ppg), pump 91 bbls (440 sx) 15.8 ppg cement(15.8 ppg,yield 1.16 cuft/sx),6.2 bbls MP(12.5 ppg), rig displace w/243 bbls 11 ppg mud to balance plug. POOH slow f/15598'to 14561', install nerf ball in string, pump nerf ball down to clean pipe,continue to pump a total of 1490 bbls. POOH f/14561'to 13153'. 00:00 00:15 0.25 3,646 3,646 INTRM1 RIGMNT SFTY P Pre job safety meeting on slip and cut drill line. 00:15 02:00 1.75 3,646 3,646 INTRM1 RIGMNT SLPC P Slip and cut 60'of 1-3/8"drill line. 02:00 10:15 8.25 3,646 14,372 INTRM1 PLUG TRIP P Con't RIH w/cement stinger on 5" DP f/3646'to 14,372'-PU 250 SO (installing Super Sliders on 5"DP f/ std#125 to 143-3 sliders/std) Page 22 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 11:30 1.25 14,372 14,372 INTRM1 PLUG OTHR T Lost high line power-Put#2 CAT on line-Work pipe-Trouble shooting power problem-Breaker trip at switch gear trailor 11:30 13:15 1.75 14,372 15,598 INTRM1 PLUG TRIP P Cont. RIH w/3 1/2"tbg stinger on 5" DP f/14,372'to 15,598'(Installing Super Pliders f/std#144 to#156) 13:15 16:15 3.00 15,598 15,598 INTRM1 PLUG CIRC P MU top drive-Establish-Circ and condition mud&hole for cement plug -Stage pumps up to 8 bbls/min @ 980 psi,then 10 bpm w/1200 psi. 16:15 16:30 0.25 15,598 15,598 INTRM1 PLUG OTHR P Blow down the top drive. Remove bell guide on top drive. 16:30 16:45 0.25 15,598 15,598 INTRM1 PLUG RURD P Pre job safety meeting,then rig up cementing equipment. 16:45 17:00 0.25 15,598 15,598 INTRM1 PLUG CMNT P Dowell pressure test to 3000 psi. Then pump 37.5 bbls mudPush II (12.5 ppg)@ 4 bpm w/400 psi.Mix cement to 15.8 ppg(yield 1.16 cuft/sx,mix water 5.078 gal/sx, thickening time 5 hr 24 min) 17:00 17:30 0.50 15,598 15,598 INTRM1 PLUG CMNT P Dowell pump 91 bbls(440 sx)of 15.8_ ppg cement @ 4-5 bpm w/400-900 psi,follow w/6.2 bls of mudPush (12.5 ppg)in the pipe, pumping 4 bpm w/450 psi. Shut in the drill pipe. Flush Dowell lines to rig floor. 17:30 18:00 0.50 15,598 15,598 INTRM1 PLUG DISP P Rig displace cement w/11ppg mud, pumping 8 bpm w/initial 270 psi, when mud push was at the tail of tbg the pressure was 830 psi.Quit reciprocating pipe.Continued pumping 8 bpm w/830 psi.The pressure was 860 psi once cement was at the tail. Continued pumping 8 bpm until 200 bbls was displaced (1150 psi)slowed to 6 bpm w/760 psi, slowed to 4 bpm w/490 psi initial and 530 psi after pumping 235 bbls, slowed to final of 2.5 bpm w/ 370 psi and final of 390 psi.Shut down after pumping 243 bbls to balance cement plug. Full returns throughout. 18:00 18:15 0.25 15,598 15,598 INTRM1 PLUG RURD P Rig down cementing equipment. 18:15 20:00 1.75 15,598 14,561 INTRM1 PLUG TRIP P Pull out of the cement slow(10-13 ft/min)f/15598'to 14561'. Page 23 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:30 2.50 14,561 14,561 INTRM1 PLUG CIRC P Install nerf ball to wipe drill pipe and tubing. PU wt 250k, SO wt 155k. Circulate nerf ball down and out string pumping 3 bpm w/430 psi, increase to 6 bpm w/660 psi,then 9 bpm w/1000 psi until ball exited string. Increased rate to 12 bpm w/ 1580 psi while continuing to circulate bottoms up. Noticed a small amount of mudpush at surface,continued to circulate and noticed an increase of PH to 11.59 while circulating surface to surface(Cement wiped from string).Circulated a total of 1490 bbls. 22:30 00:00 1.50 14,561 13,153 INTRM1 PLUG TRIP P Blow down the top drive,then pull out of the hole f/14561'to 13153'(130 stands of 5"in the hole). 03/16/2012 Spot a 30 ppb fresh gel pill f/13153'to 12872', POOH to 12872', RU to place kick off plug, PJSM, circ, Dowell PT to 3k, Pumped 29.3 bbls 12.5 ppg MudPush-56.8 bbls 17.0 ppg cement w/additives-2.5 bbls 12.5 ppg MudPush-Displaced to equalize w/202 bbls 11.0 ppg LSND mud @ 8 bbls/min @ 850 psi, POOH slow f/12872'to 12120', load nerf ball,pump to clean pipe&circ BU, POOH f/12120'to 11648', pump dry job, con't POOH 11648'to 9772', noticed cement rings in dp, break all connections cleaning cement rings out of tool joints to 7508', Held safety stand down, pumped 20 bbls of fresh water attempting to clean rings f/tool joints,con't POOH f/7508'to 4306'clean each tool joint, held safety stand down meeting, con't POOH f/ 4306'to 2230'cleaning cement rings f/each connection. 00:00 00:45 0.75 13,153 13,153 INTRM1 PLUG CIRC P Spotted gel pill f/13,153'to 12,872' (32 bbls)@ 10 bbls/min @ 1120 psi -PU wt.235 SO wt 145 00:45 01:00 0.25 13,153 12,872 INTRM1 PLUG TRIP P Blow down TD-POOH f/13,153'to 12,872'- PU wt 235 SO wt 145 01:00 01:15 0.25 12,872 12,872 INTRM1 PLUG CIRC P PU to set plug#2(head pin ,valves &cement hose)Circ @ 4 bbls/min @ 510 psi 111 01:15 03:15 2.00 12,872 12,872 INTRM1 PLUG CMNT P__Set kick_off plug,as followms:Pup t/ �4,L fresh water to establish circ-Test lines to 3000 psi-Pumped 29.3 bbls 12.5 ppg MudPush-56.8 bbls 17.0 ppg cement w/additives-2.5 bbls 12.5 ppg Mud Push-Displaced to equalize w/202 bbls 11.0 ppg LSND mud @ 8 bbls/min @ 850 psi-RD cmt. line&head pin-Blow down line 03:15 04:30 1.25 12,872 12,120 INTRM1 PLUG TRIP P POOH on TT f/12,872'to 12,120' PU wt.225 SO wt 145 04:30 06:30 2.00 12,120 12,120 INTRM1 PLUG CIRC P Load Nerf ball into top of DP-Pump ball down thru cement string to clear cement residue-&circ btms up @ 9 bbls/min @ 950 psi- PU wt 205 SO wt 145 06:30 07:45 1.25 12,120 11,648 INTRM1 PLUG TRIP P Blow down TD-Flow ck well static- Install bell guide-POOH on TT f/ 12,120'to 11,648' -PU wt 225 SO wt 145 07:45 08:00 0.25 11,648 11,648 INTRM1 PLUG CIRC P Flow ck- Pump dry job-Blow down TD Page 24 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:15 2.25 11,648 9,772 INTRM1 PLUG TRIP P Cont. POOH on TT f/11,648'to 9772' 9 Observed cement rings in DP 10:15 14:15 4.00 9,772 7,508 INTRM1 PLUG TRIP P 1 Cont. POOH on TT f/9772'to 7508'- breaking each connection checking for&cleaning out cement rings in DP 14:15 14:45 0.50 7,508 7,508 INTRM1 PLUG SFTY P Held Safety Stand Down with rig crew, ball mill, DD,MWD, FMC, Mud Engineer 14:45 16:30 1.75 7,508 7,508 INTRM1 PLUG CIRC P Pumped 20 bbls fresh water at 15 bbls/min @ 1750 psi(attempt to flush out cement ring in DP-slowed pumps to 10 bbls/min @ 960 psi w/water out of pipe-circ btms up- pumped dry job 16:30 16:45 0.25 7,508 7,508 INTRM1 PLUG OWFF P Monitor well @ 7508'-static. 16:45 20:15 3.50 7,508 4,306 INTRMI PLUG TRIP P Cont. POOH on TT f/7508'to 4306'- breaking each connection checking for&cleaning out cement rings in DP 20:15 20:45 0.50 4,306 4,306 INTRMI PLUG SFTY P Held Safety Stand Down with rig crew, ball mill, DD, MWD, Mud Engineer. Note: Held another stand down w/ catering personnel(Baker)and Spill tech later in the day. 20:45 00:00 3.25 4,306 2,230 INTRM1 PLUG TRIP P Cont. POOH on TT f/4306'to 2230'- breaking each connection checking for&cleaning out cement rings in DP.Observed well to be static @ 3646'. 03/17/2012 Con't POOH f/2230'to 913'cleaning cement rings f/each connection, RU tbg equipment, PJSM, POOH L/D 29 jts of 3-1/2"EUE tbg and mule shoe, Pull wear bushing, install test plug, RU/then test BOPE w/5"test joint-witness of test waived by AOGCC inspector Bob Noble. Replace HCR valve on choke line. Retest valve and hose connection-OK. R/D test equipment, clean floor drip pan and drain lines, PJSM, MU BHA#3 to 270'. 00:00 02:15 2.25 2,230 913 INTRM1 PLUG TRIP P Cont POOH f/2230'to 913'cleaning cement rings f/each connection 02:15 02:45 0.50 913 913 INTRMI PLUG RURD P PJSM-RU to pull 3 1/2"tbg(cmt stinger) 02:45 03:15 0.50 913 913 INTRMI PLUG SFTY P Pre job safety meeting on laying down 29 joints of 3-1/2"9.3 ppf L-80 EUE-m tubing and mule shoe.-Flow ck well static 03:15 05:45 2.50 913 0 INTRM1 PLUG PULD P Lay down 3-1/2"cementing stinger f/ 913'(2 XO's-29 jts-mule shoe) 05:45 06:45 1.00 0 0 INTRM1 PLUG OTHR P RD tbg equipment-clean up rig floor -Flow ck well static 06:45 07:30 0.75 0 0 INTRMI WHDBO OTHR P RU to pull wear bushing-unable to pull w/tagger-MU 5"elevators-Pull wear bushing loose w/30 k-Set lower test plug 07:30 08:45 1.25 0 0 INTRM1 WHDBO BOPE P RU to test BOPE-fill stack&choke manifold w/water Page 25 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 16:00 7.25 0 0 INTRM1 WHDBO BOPE P Test BOPE as follows:annular to 250&2500 psi-Upper pipe rams, choke maniflod valves,choke&kill line manual&HCR valves-Floor safety&dart valves-Auto&manual IBOP valves-Lower pipes to 250& 3500 psi-Performed accumulator n D recovery test-LD test jt. (5")-tested 1✓� ,/ blind rams to 250&3500 psi- /sl Performed draw down test on super &manual chokes to 1100 psi- Witnessing of test waived by Bob Noble w/AOGCC Note: Electrician tested gas alarms. Note-HCR choke failed to test- serviced valve and attempted to retest-held low test-wouldn't hold high pressure test. Blow down lines-Pull&LD test jt. 16:00 16:15 0.25 0 0 INTRM1 WHDBO SFTY T PJSM on changing HCR choke valve. Note that valve had been changed two weeks ago on previous test, tested and passed. Monitor well on the trip tank. 16:15 18:15 2.00 0 0 INTRM1 WHDBO RGRP T Change HCR choke valve with another HCR valve-Attach choke line hose and secure w/safety line.. 18:15 19:30 1.25 0 0 INTRM1 WHDBO RURD T Install FMC lower test plug. Rig up to test. Fill stack with water,work out air. 19:30 20:00 0.50 0 0 INTRM1 WHDBO BOPE T Test flange connection on choke line hose downstream of choke valve to 250 psi low and 3500 psi high(tested top pipe rams, HCR kill line, choke valves 2,4,6 and 9)Test HCR on choke line side to 250 psi low and 3500 psi high(tested top pipe rams, choke HCR valve and kill HCR valve). Hold each test f/5 minutes.Charted tests. 20:00 20:30 0.50 0 0 INTRM1 WHDBO RURD P Pull FMC test plug. Pulled 10k over w/blocks to pull.Change seals on wear bushing then install FMC wear bushing(4.35'long, 10"ID). Push wear ring w/5k to seat. Run in lockdown screws. 20:30 21:00 0.50 0 0 INTRM1 WHDBO OTHR P PJSM,then blow down choke manifold,choke line and kill line. 21:00 21:30 0.50 0 0 INTRM1 DRILL OTHR P Clean floor drip pans and drain lines. 21:30 21:45 0.25 0 0 INTRM2 DRILL SFTY P Pre job safety meeting on picking up BHA#3. Page 26 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 0 270 INTRM2 DRILL PULD P Make up BHA#3(Schlumberger rotary steerable): Hycolog 9-7/8" SKH516M-B2C(ser#A154696), Xceed 675,arcVision,TeleScope, nm crossover, NM stab, (3) NM flex drill collars,saver sub w/corrosion ring in the top,(1)stand of HWDP- includes jars in the middle of stand to 270'. 03/18/2012 Shallow test MWD @ 270'-calibrate block height, MU BHA to 636'-Rotate BHA f/ 770'to 821'(to pass thru TAM PC @ 790')-RIH to 7984'(tight hole @ 7754'to 7780'),CBU @ 7984', con't RIH f/7984'to 12031', Circ &dilute mud to lower MW f/11 ppg to 10.5 ppg,wash f/12031'to 12270', ream cement f/12270'to 12475'. 00:00 01:00 1.00 270 270 INTRM2 DRILL OTHR P Shallow test MWD @ 270', pumping 508 gpm w/660 psi,525 gpm w/720 psi.-Blow down TD-Calibrate block height f/MWD 01:00 02:00 1.00 270 915 INTRM2 DRILL TRIP P RIH f/270'-MU remainder of BHA to 636'- Make up a stand of 5"drill pipe, RIH, make a top drive connection on stand#2,slack off to 770',then rotate 40 rpm w/4k ftlbs of torque, rotate through TAM port collar(790'),took 3k, PU, rotate through again and did not see again, rotated to 821'. Make a connection on stand#3,slack off f/821'to 915'. Did not see 9 an thin (stab below Y TAM port collar). Break off top drive. 02:00 09:00 7.00 915 7,984 INTRM2 DRILL TRIP P Cont.to RIH w/BHA#3 f/915'to 7984'-Filling pipe every 20 stds. (Observed well @ 10 3/4"shoe- static-Worked thru tight hole f/ 7754'to 7780' 09:00 10:30 1.50 7,984 7,984 INTRM2 DRILL CIRC P Stage pump up to 400 gpm @ 1170 psi w/140 rpm @19.5ktorque- Circ btms-PUwt195 SO wt. 135 10:30 12:00 1.50 7,984 9,585 INTRM2 DRILL TRIP P Cont. RIH w/BHA#3 f/7984'to 9585' PU wt 210 SO wt 130 12:00 15:30 3.50 9,585 12,031 INTRM2 DRILL TRIP P Cont. RIH w/BHA#3 f/9585'to 12,031' ( Filling pipe every 20 stds) 15:30 20:30 5.00 12,031 11,749 INTRM2 DRILL CIRC P Stage pump up to 17.2 bbls/min @ 2500 psi w/140 rpm's @ 27 K toqrque-making 750 bbl whole mud dilution&lowering mud wt.to 10.5 ppg.Working pipe f/11937'to 12031',then start setting back stands while circ to 11749'(118 stands in the hole). 20:30 20:45 0.25 11,749 12,031 INTRM2 DRILL TRIP P Trip in the hole f/11749'to 12031'. 20:45 22:00 1.25 12,031 12,270 INTRM2 DRILL WASH P Make a top drive connection,then wash in the hole f/12031'to 12270'. Set down on stringers:20k @ 12162' and again @ 12175', 10k @ 12216' and 12230',20k again @ 12269'. Page 27 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment _ 22:00 00:00 2.00 12,270 12,475 INTRM2 DRILL REAM P Start reaming in the hole f/12270'to 12475'.WOB 2-7k. Rotating 140 rpm /1/ w/27.5k ft lbs of torque. Pumping 725 gpm w/2650 psi. PU without rotary 240k,SO wt 160k, Rot wt 190k. 03/19/2012 Circ&cond mud-high torque-28k ft lbs-unable to maintain rotation without moving pipe,work pipe f/12475' to 12218',decision to POOH to see if/when torque reduction occurs-obtain T&D every 10 stands, pump/POOH f/12218'to 9960', Back ream out f/9960'to 9395',pump hi vis sweep,con't backream f/9395'to 5532', pump hi vis sweep,con't backream f/5532'to 4405', pump hi vis sweep. 00:00 04:30 4.50 12,475 12,218 INTRM2 DRILL TRIP P Work pipe @ 12,475'-high torque (unable to rotate without slacking off) pumping 720 gpm @ 2670 psi w/100 to 140 rpm's @ 28 k torque-PU wt 290 SO wt 150-Pulled back to 12,312'(2 stds) Pumped weighted (12.5 ppg)hi-vis sweep w/5ppb nut plug-Pulled back to 12,218'(1 std)- flow ck well static 04:30 08:45 4.25 12,218 9,960 INTRM2 DRILL TRIP T POOH w/pumps f/12,218'to 9960' @ 750 gpm @ 2501 psi-obtaining Torque&Drag data each 10 stds - PU wt 240 SO wt 133 08:45 09:45 1.00 9,960 9,395 INTRM2 DRILL TRIP T BROOH f/9960'to 9395'@ 750 gpm @ 2510 psi @ 140 rpm's @ 24 k torque-PU wt 250 SO wt 130 09:45 11:30 1.75 9,395 9,395 INTRM2 DRILL CIRC T Pumped Hi-vis sweep w/5 ppb nut plug medium-@ 800 gpm @ 2750 psi w/140 rpm's @ 24 k torque- Observed nut plug back @ shakers 271 bbls late-some increase in the amount of cuttings @ shakers 11:30 12:00 0.50 9,395 9,209 INTRM2 DRILL TRIP T Cont. BROOH f/9395'to 9209'@ 750 gpm @ 2470 psi w/140 rpm's @ 24 k torque 12:00 19:30 7.50 9,209 5,532 INTRM2 DRILL TRIP T Cont. BROOH f/9209'to 5532'@ 750 gpm @ 2470 to 2040 psi w/140 rpm's @ 24 to 15 k torque 19:30 20:30 1.00 5,532 5,532 INTRM2 DRILL CIRC T Pumped Hi-vis sweep w/5 ppb nut plug medium-@ 800 gpm @ 2240 psi w/140 rpm's @ 15 k torque- Observed nut plug back @ shakers 175 bbls late-some increase in the amount of cuttings @ shakers. 20:30 23:30 3.00 5,532 4,405 INTRM2 DRILL TRIP T Cont. BROOH f/5532'to 4405'@ 750 gpm @ 2040 to 1970 psi w/140 rpm's @ 15 to 14 k torque. PU wt 152k,SO wt 112, Rot wt 130k, Rot torque 13k. Page 28 of 72 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 23:30 00:00 0.50 4,405 4,405 1INTRM2 DRILL CIRC T Pumped Hi-vis sweep w/5 ppb nut plug medium-@ 800 gpm @ 19500 psi w/140 rpm's @ 13 k torque- Observed nut plug back @ shakers 38 bbls late(12-12-1/4"avg hole size in 755'of open hole)-some increase in the amount of cuttings @ shakers. Also got one of the nerf balls back to surface intact. Before sweep: PU wt 152,SO wt 112, Rot wt 130k,torque @ 140 rpm 13k.After sweep: PU wt 150k, SO wt 122k,Torque @ 30 rpm 12k ft lbs. 03/20/2012 Con't backream f/4405'to 3463', pump hi vis sweep, monitor well-static, PJSM,slip and cut drill line, POOH on elevators f/3463'to 2992', monitor well-static, pump dry job, POOH f/2992'to 175', monitor well-static, stand back flex collars, L/D BHA#3,clean floor,change saver sub on top drive, PJSM, RU tubing equipment, pull wear bushing,set test plug,test w/3-1/2"test joint,set wear bushing, PJSM, MU Baker ECP, MU 3-1/2" tubing to 947', RIH w/stinger on 5"drill pipe f/947'to 4056'. 00:00 00:15 0.25 4,405 4,405 INTRM2 DRILL OWFF T Monitor well-static. 00:15 02:15 2.00 4,405 3,463 INTRM2 DRILL TRIP T Cont backream f/4405'to 3463'. Pumping 750 gpm w/1970 to 1850 psi, 140 rpm in the open hole,then 80 rpm inside of 10-3/4"casing, torque 13k to 12k ft lbs. PU wt 142k, SO wt 105k. Note:25k overpull @ 4393'-worked through-OK.44k overpull @ 3990'- worked through-OK. 02:15 03:15 1.00 3,463 3,463 INTRM2 DRILL CIRC T Pump 34 bbl hi vis sweep w/5 ppb nut plug. Note:Significant amount of small cuttings with sweep. Nerf ball#2 showed up at the shakers with bit inside of casing. 03:15 03:30 0.25 3,463 3,463 INTRM2 DRILL OWFF T Monitor well-static. 03:30 03:45 0.25 3,463 3,463 INTRM2 DRILL SFTY T Pre job safety meeting-slip and cut drill line. 03:45 04:45 1.00 3,463 3,463 INTRM2 RIGMNT SLPC T Slip and cut 60'of 1-3/8"drill line. 04:45 05:15 0.50 3,463 3,463 INTRM2 RIGMNTSVRG T Service rig. 05:15 06:00 0.75 3,463 2,992 INTRM2 DRILL TRIP T POOH on elevators f/3463'to 2992'. Monitor well on the trip tank. 06:00 06:15 0.25 2,992 2,992 INTRM2 DRILL OWFF T Monitor well-static. 06:15 06:30 0.25 2,992 2,992 INTRM2 DRILL CIRC T Pump a 29 bbl 12.5 ppb dry job. 06:30 06:45 0.25 2,992 2,992 INTRM2 DRILL OTHR T Blow down the top drive. 06:45 09:15 2.50 2,992 175 INTRM2 DRILL TRIP T POOH f/2992'to 175'. 09:15 09:30 0.25 175 175 INTRM2 DRILL OWFF T Monitor well-static 09:30 11:30 2.00 175 0 INTRM2 DRILL PULD T Stand back flex collars, L/D BHA#3. 11:30 12:00 0.50 0 0 INTRM2 DRILL OTHR T Clean floor. Page 29 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 0 0 INTRM2 RIGMNT SFTY T Pre job safety meeting on chnaging the 4-1/2"IF saver sub on the top drive. 12:15 13:45 1.50 0 0 INTRM2 RIGMNT SVRG T Change saver sub on top drive. Inspect grab dies.Tighten bolts, rewire-tie bell guide bolts. 13:45 14:00 0.25 0 0 INTRM2 PLUG SFTY T Pre job safety meeting on rigging up 3-1/2"tubing equipment. 14:00 14:15 0.25 0 0 INTRM2 PLUG RURD T RU 3-1/2"tubing equipment. 14:15 14:30 0.25 0 0 INTRM2 WHDBO SFTY T Pre job safety meeting on testing w/ 3-1/2"test joint. 14:30 14:45 0.25 0 0 INTRM2 WHDBO RURD T Pull FMC wear bushing with the blocks,set FMC lower test plug. 14:45 15:00 0.25 0 0 INTRM2 WHDBO SFTY T Pre job safety meeting on rigging up to test BOPE. 15:00 15:15 0.25 0 0 INTRM2 WHDBO RURD T Rig up to test with 3-/12"test joint. 15:15 16:00 0.75 0 0 INTRM2 WHDBO BOPE T Test w/3-1/2"test joint.Test annular to 250 psi low and 2500 psi high. Test top pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. 16:00 16:30 0.50 0 0 INTRM2 WHDBO RURD T Pull FMC test plug,set FMC wear bushing(10"ID). 16:30 16:45 0.25 0 0 INTRM2 PLUG SFTY T Pre job safety meeting on running 3-1/2"EUE-m 9.3 ppf L-80 tubing stinger. 16:45 20:15 3.50 0 947 INTRM2 PLUG PULD T Pick up Baker ECP, Make up 29 joints of 3-1/2"tubing with two crossovers to 947'. Fill string from top w/hose. 20:15 00:00 3.75 947 4,056 INTRM2 PLUG TRIP T RIH w/Baker External casing packer on 5"drill pipe f/947'to 4056'. Fill every stand,top off every 5 stands. 03/21/2012 Con't to RIH w/stinger on 5"drill pipe f/4056'to 8326', Break circulation,make up 15'pup-install wiper plug, RIH to 8332', circ down the wiper plug, pickup liner wiper plug at top of ECP, inflate Baker 7"ECP, pressure to 3300 psi to release, PU then circ prior to cement job w/stinger @ 8302'. Dowell pump balanced plug, Rig displace, POOH to 7327', circ, POOH f/7327'to 4251',circ, pump 50 bbl 30 ppb gel pill(300'pill), POOH to 3950', circ, Dowell pump balanced plug, rig displace, POOH to 2993,circ, POOH to 920',circ, RU 3-1/2" tongs. 00:00 04:00 4.00 4,056 8,295 INTRM2 PLUG TRIP T Con't to RIH w/stinger on 5"drill pipe f/4056'to 8295'. Fill every stand,top off every 5 stands. 04:00 04:30 0.50 8,295 8,326 INTRM2 PLUG CIRC T Make up single f/pipe shed, break circulation. Staged up f/1 bpm w/ 210 psi,2 bpm w/250 psi,3 bpm w/ 300 psi,4 bpm w/330 psi,5 bpm after 40 bbls pumped to 380 psi. Pumped a total of 72 bbls. 04:30 04:45 0.25 8,326 8,332 INTRM2 PLUG PULD T Make up 15'pup-install dp wiper plug, RIH to 8332'. PU wt 190k,SO wt 125k. Page 30 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:15 0.50 8,332 8,332 INTRM2 PLUG CIRC T Circ down the dp wiper plug, pickup liner wiper plug at top of ECP (latchup @ 129.7 bbls),continue pumping to land liner wiper plug into insert landing collar in the 7"pup joint below the ECP. Pressure to 500 psi and hold. 05:15 05:45 0.50 8,332 8,332 INTRM2 PLUG PACK T Inflate Baker 7"ECP_Stage pressure up in 500 psi increments to 1500 psi, ed' then increase to inflate packer. Pressured to 2800 psi, let bleed Q�J down to 720 psi. Presssure back up to 3300 psi to release. Left shoe @ 8331,74',_bottom of element @, / 8318.84',top of element @ 8309',top ✓ of assemble @ 8304.7'. 05:45 08:00 2.25 8,332 8,332 INTRM2 PLUG CIRC T Circulate and condition hole for cement. Pumping 5 bpm w/320 psi, then 8 bpm w/480 psi. 08:00 08:15 0.25 8,332 8,302 INTRM2 PLUG RURD T Pre job safety meeting,then lay down 15'5"pup joint to have cementing stinger @ 8302'. Blow down the top drive, remove bell guide. Rig up cementing line. 08:15 08:30 0.25 8,302 8,302 INTRM2 CEMEN-CMNT T Dowell pump 2 bbls water to floor to prime lines. Pressure test lines to 3000 psi. 08:30 09:00 0.50 8,302 8,302 INTRM2 CEMEN-CMNT T Dowell mix and pump @ 5 bpm 380 to 245 psi--39 bbls of 12.5 ppg mud push,follow w/60.1 bbls(291j sx)of 15.8 ppg class G wfAdds (yield 1.16 cuft/sx, mix water 5.08 gal/sx,thickening time 4 hr 52 min)- pumping 4.8 bpm w/160 to 120 psi, then 2.6 bbls of 12.5 ppg mudPush. Shut down,flush lines to floor. 09:00 09:30 0.50 8,302 8,302 INTRM2 CEMEN"DISP T Rig displace w/10.5 ppg mud to balance cement plug. Rig pumped 124 bbls Pump @ 8 bpm w/265 to 880 psi .Shut down. CIP @ 0920 hrs 3-21-2012. 09:30 09:45 0.25 8,302 8,269 INTRM2 CEMEN-PULD T Lay down a single of 5"drill pipe f/ 8302'to 8269'. 09:45 10:30 0.75 8,269 7,327 INTRM2 CEMEN"TRIP T Pull out of the hole slow f/8269'to 7327'to allow cement to fall out of cement stinger. PU wt 170k,SO wt 120k.Monitor well on the trip tank. 10:30 12:00 1.50 7,327 7,327 INTRM2 CEMEN-CIRCT Insert 5.85"OD nerf ball into drill string. Pump 31 bbls of water,follow w/mud and pump surface to surface to cleanup drill string and stinger. Pump 600 gpm w/1160 psi. 12:00 12:15 0.25 7,327 7,327 INTRM2 CEMEN"SFTY T Pre job safety meeting. 12:15 12:30 0.25 7,327 7,327 INTRM2 CEMEN-OTHR T Blow down the top drive 12:30 12:45 0.25 7,327 7,327 INTRM2 CEMEN-OWFF T Monitor well-static. Page 31 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 14:30 1.75 7,327 4,219 INTRM2 CEMEN"TRIP T Trip out of the hole f/7327'to 4219', pick up a single, run in to 4251'. 14:30 14:45 0.25 4,219 4,251 INTRM2 CEMEN-PULD T Pick up a single, run in to 4251'. 14:45 15:00 0.25 4,251 4,251 INTRM2 CEMEN"CIRC T Break circulation,then spot 50 bbls, 30 ppb gel pill as a balanced pill to cover 300'of open hole 4250'to 3950'. Pump @ 300 gpm w/360 psi. 15:00 15:15 0.25 4,251 4,251 INTRM2 CEMEN'OWFF T Monitor well-static. 15:15 15:30 0.25 4,251 3,936 INTRM2 CEMEN-TRIPT Lay down a single, POOH f/4219'to 3936'. 15:30 15:45 0.25 3,936 3,950 INTRM2 CEMEN"PULD T Pick up a 15'pup joint, run in to 3950'. 15:45 16:00 0.25 3,950 3,950 INTRM2 CEMEN-RURD T Rig up headpin and cementing equipment. 16:00 16:15 0.25 3,950 3,950 INTRM2 CEMEN-CIRCT Circulate and prepare to pump 17 ppg cement f/kick off plug. 16:15 17:00 0.75 3,950 3,950 INTRM2 CEMEN-CMNT T Dowell flood lines w/water,pressure test to 3000 psi, mix and pump @ 4.8 bpm w/150 psi--25 bbls MudPush spacer 12.5 ppg, mix and pump @ 4 bpm w/100 to 80 psi--63 bbls(354 sx)of 17 ppg class"G"w/ adds (yield 1.01 cuft/sx, mix water 3.894 gal/sx,thickening time 3hr 24 min),follow w/2.6 bbls of 12.5 ppg mud push in the pipe. Dowell clean lines to floor. CIP 1708 hrs 3-21-2012. 17:00 17:15 0.25 3,950 3,950 INTRM2 CEMEN-DISP T Rig displace cement pumping 386 gpm w/300-750 psi. Pumped 48.8 bbls,then shut down. 17:15 17:30 0.25 3,950 3,940 INTRM2 CEMEN-RURD T Rig down cementing equipment. Lay down pup joint. 17:30 18:15 0.75 3,940 2,993 INTRM2 CEMEN'TRIP T Trip out of the hole slow f/3940'to 2993'. PU wt 115k,SO wt 105k. 18:15 18:30 0.25 2,993 2,993 INTRM2 CEMEN"SFTY T Pre job safety meeting, Load 5.85" OD nerf ball in pipe. 18:30 19:45 1.25 2,993 2,993 INTRM2 CEMEN"CIRC T Pump 30 bbls of water,follow w/10.5 ppg mud to clean pipe. Pump 14 bpm w/650 psi, rotate 40 rpm w/6k ft lbs of torque. Recip 2993'to 2963'. 19:45 20:00 0.25 2,993 2,993 INTRM2 CEMEN-SFTY T Pre job safety meeting on trip out. Blow down the top drive. 20:00 22:00 2.00 2,993 920 INTRM2 CEMEN-TRIP T Trip out of the hole f/2993'to 920'. 22:00 22:15 0.25 920 920 INTRM2 CEMEN-OWFF T Monitor well-static. 22:15 22:30 0.25 920 920 INTRM2 CEMEN-SFTY T Pre job safety meeting Ciculating/clean floor. 22:30 23:15 0.75 920 920 INTRM2 CEMEN-CIRCT Circulate 750 gpm w/640 psi to clean up pipe and hole 23:15 23:30 0.25 920 920 INTRM2 CEMEN-OTHR T Blow down top drive. 23:30 23:45 0.25 920 920 INTRM2 CEMEN-OWFF T Monitor well-static. 23:45 00:00 0.25 920 920 INTRM2 CEMEN'SFTY T Pre job safety meeting, rig up tubing tongs. Page 32 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/22/2012 24 hr Summary Lay down 29 joints of 3-1/2"9.3 ppf L-80 EUE-m tubing,crossover 3-1/2"EUE x 2-7/8"EUE, 10'2-7/8"EUE pup joint,triple connect sub and collett,monitor well, clean floor, RU elevators&bell guide f/top drive, PJSM on BHA and Safety Pause, MU BHA#4 to 176', RIH to 1870',shallow test MWD, MU 2nd ghost reamer, RIH to 3101',wash down f/3101'to 3856', pump nut plug sweep to guage hole,confirm tag @ 3868'w/10k WOB, POOH f/3868'to 176', la down BHA#4, clean floor, RU 3-1/2"tubing equipment. 00:00 02:00 2.00 920 0 INTRM2 CEMEN-PULD T Pull out of the hole laying down 29 joints of 3-1/2"9.3 ppf L-80 EUE-m tubing,crossover(3-1/2"EUE x 2-7/8"EUE, 10'2-27/8"EUE pup joint,triple connect sub. 02:00 02:15 0.25 0 0 INTRM2 CEMEN-OWFF T Monitor well-static. 02:15 03:45 1.50 0 0 INTRM2 CEMEN"RURD T Clean floor, Lay down tubing tongs, change elevators, install bell guide on the top drive. 03:45 04:15 0.50 0 0 INTRM2 CEMEN"SFTY T Pre job safety meeting on picking up BHA#4.Safety Pause discussion w/ crew. 04:15 05:45 1.50 0 176 INTRM2 CEMEN-PULD T Make up BHA#4 to 176' 05:45 06:15 0.50 176 1,870 INTRM2 CEMEN-TRIP T Run in the hole w/5"HWDP f/176' to 646'(top of HWDP), make up 1st 9-7/8"Weatherford ghost reamer, make up 13 stands of 5"drill pipe to 1870'. Note: Rotate bit through the TAM port collar in the 10-3/4"casing @ 790'. 06:15 06:45 0.50 1,870 1,870 INTRM2 CEMEN-DHEQ T Shallow test Schlumberger MWD @ 1870'. Pumping 500 gpm w/770 psi. 06:45 09:45 3.00 1,870 3,101 INTRM2 CEMEN"TRIP T Make up 2nd Weatherford 9-7/8" ghost reamer.Trip in the hole w/5" drill pipe. Filled pipe @ 2063'. Obtain torque and drag every 3rd stand going in the hole. 09:45 12:00 2.25 3,101 3,856 INTRM2 CEMEN-WASH T Wash down from 3101'to 3856'. Pumping 450 gpm w/930 psi, rotate 50 rpm w/12.5k ft lbs of torque. Rotating weight 128k. 12:00 12:15 0.25 3,856 3,856 INTRM2 CEMEN-SFTY T Pre job safety meeting. 12:15 13:00 0.75 3,856 3,868 INTRM2 CEMEN"WASH T Wash down f/3856'to tag @ 3868'. Pumping 450 gpm w/900 psi, rotate 45 rpm w/12k ft lbs of torque. 13:00 14:00 1.00 3,868 3,868 INTRM2 CEMEN"CIRC T Circulate @ 3855', pump a nut plug sweep to guage the hole. Pump 500 gpm w/1050 psi, rotate 90 rpm w/ 12k ft lbs of torque. 14:00 14:15 0.25 3,868 3,868 INTRM2 CEMEN"OTHR T Pre job safety meeting,then blow down the top drive. Confirm tag @ 3868'w/10k WOB. 14:15 15:15 1.00 3,868 3,291 INTRM2 CEMEN-TRIPT Pull out of the hole to install more cement,trip f/3868'to 3291'. Improper hole fill. 15:15 15:30 0.25 3,291 3,666 INTRM2 CEMEN-TRIPT Trip in f/3291'to 3666' 15:30 15:45 0.25 3,666 3,666 INTRM2 CEMEN"SFTY T Pre job safety meeting. Page 33 of 72 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:45 16:00 0.25 3,666 3,666 INTRM2 CEMEN-CIRCT Circulate bottoms up, pumping 600 gpm w/1300 psi, rotate 90 rpm w/ 12k ft lbs of torque. 16:00 16:15 0.25 3,666 3,666 INTRM2 CEMEN-OWFF T Pre job safety meeting,then blow down the top drive.Monitor well- static. 16:15 21:30 5.25 3,666 176 INTRM2 CEMEN-TRIPT Pull out of the hole f/3666'to 176' 21:30 21:45 0.25 176 176 INTRM2 CEMEN"SFTY T Pre job safety meeting on laying down BHA. 21:45 23:00 1.25 176 176 INTRM2 CEMEN"PULD T Lay down BHA#4 23:00 23:30 0.50 176 0 INTRM2 CEMEN"RURD T Clean floor. 23:30 00:00 0.50 0 0 INTRM2 CEMEN-RURD T Rig up tubing tongs. Prepare to PU 3-1/2"9.3 ppf L-80 EUE-m tubing stinger. 03/23/2012 Make up 3-1/2"cement stinger to 912',Trip in on elevators w/5"drill pipe to 3868',circ&cond mud f/ cement, rig up f/cementing, PJSM, Pump balanced cement plug-34 bbls 12.5 ppg mud push, 50 bbls 17 ppg class"G"w/adds, 3.5 bbls 12.5 ppg mudPush,displ w/47 bbls of 10.5 ppg mud,shut down. POOH f/3868' to 2890', load nerf ball, pump 30 bbls water,follow w/10.5 ppg mud, puming surface to surface to clean pipe, pull out of the hole, lay down 3-1/2"tubing, Make up BHA#5(9-7/8"rotary steerable)to 1878.99',trip in with 5"drill pipe to 2912',wash down to 3007'. Prepare to slip and cut drill line. 00:00 00:15 0.25 0 0 INTRM2 CEMEN-SFTY T Pre job safety meeting on PU 3-1/2" 9.3 ppf L-80 EUE-m tubing tail f/ cement stinger. 00:15 01:30 1.25 0 912 INTRM2 CEMEN-PUTB T Make up mule shoe,29 jts and two crossovers to 912. 01:30 01:45 0.25 912 912 INTRM2 CEMEN-SFTY T Pre job safety meeting on rigging down tubing equipment. 01:45 02:00 0.25 912 912 INTRM2 CEMEN"RURD T Rig down tubing equipment. Rig up elevators f/5"drill pipe. 02:00 02:15 0.25 912 912 INTRM2 CEMEN"SFTY T Pre job safety meeting on tripping in w/5"drill pipe. 02:15 03:30 1.25 912 3,865 INTRM2 CEMEN-TRIP T Trip in w/cement stinger on 5"drill pipe f/912'to 3865(picked up a single). PU wt 125k, SO wt 105k. 03:30 05:00 1.50 3,865 3,865 INTRM2 CEMEN-CIRCT Circulate and condition mud and hole for cementing. Pumping 8 bpm w/ 340 psi. 05:00 05:30 0.50 3,865 3,865 INTRM2 CEMEN"RURD T Blow down the top drive. Remove bell guide on the top drive. Rig up headpin and hoses for the cement job. 05:30 06:00 0.50 3,868 3,868 INTRM2 CEMEN-CIRC T Continue to circulate prior to cement job. Pumping 8 bpm w/540 psi. 06:00 06:15 0.25 3,868 3,868 INTRM2 CEMEN"SFTY T Pre job safety meeting on cement job. Page 34 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 07:00 0.75 3,868 3,868 INTRM2 CEMEN-CMNT T Pump balanced plug for kick off: _ IL Dowell fill ines, presure test to 3000 l/ U'" psi-ok. Dowell mix and pump @ 5 bpm w/232 to 26 psi--34 bbls of 12.5 ppg mud push,follow w/50 bbls sx)of 15.8 ppg class G w/Adds (yield 1.01 cuft/sx, mix water 3.894 gal/sx,thickening time 3 hr 30 min)- pumping 4.2 bpm w/0 to 100 psi, then 3.5 bbls of 12.5 ppg mudPush. Shut down,flush lines to floor. 07:00 07:15 0.25 3,868 3,868 INTRM2 CEMEN-DISP T Rig displace w/10.5 ppg mud to balance cement plug. Rig pumped 47 bbls Pump @ 8 bpm w/200 to 110 psi .Shut down. CIP @ 0710 hrs 3-23-2012. 07:15 08:15 1.00 3,868 2,890 INTRM2 CEMEN-TRIP T Remove head pin, lay down a single, Trip out slow f/3865'to 2890'. PU wt 109k,SO wt 105k. 08:15 09:15 1.00 2,890 2,890 INTRM2 CEMEN-CIRC T Insert 5.85"OD nerf ball into pipe. Pump 30 bbls of water,follow w/10.5 ppg mud, pump surface to surface to clean up drill string. Pumping 600 gpm w/600 psi. Cut mud weight back f/10.5 ppg to 10.2 ppg. 09:15 09:30 0.25 2,890 2,890 INTRM2 CEMEN-OWFF T Monitor well-static. 09:30 10:45 1.25 2,890 912 INTRM2 CEMEN-TRIP T Pull out of the hole on the trip tank f/ 2890'to 912'. 10:45 11:30 0.75 912 912 INTRM2 CEMEN-RURD T Rig up tongs to lay down 3-1/2" tubing. 11:30 12:00 0.50 912 912 INTRM2 CEMEN"SFTY T Pre job safety meeting w/new crew- laying down 3-1/2"tubing string. 12:00 13:45 1.75 912 0 INTRM2 CEMEN"PULD T Lay down 29 joints of 3-1/2"9.3 ppf L-80 EUE-m tubing crossovers and mule shoe. 13:45 16:00 2.25 0 0 INTRM2 CEMEN"RURD T Clean floor, install bell guide on the top drive,change elevators. 16:00 16:15 0.25 0 0 INTRM2 CEMEN"SFTY T Pre job safety meeting on MU BHA #5. 16:15 18:45 2.50 0 734 INTRM2 CEMEN-PULD T Make up BHA#5(9-7/8"Rotarty steerable-Schlumberger)to 734' 18:45 19:00 0.25 734 734 INTRM2 CEMEN-DHEQ T Shallow test MWD @ 734'. Pumping 450 gpm w/680 psi. 19:00 23:30 4.50 734 2,912 INTRM2 CEMEN"TRIP T Continue to trip in w/BHA#5 f/734' to 2912', rotate through TAM port collar @ 790'w/bit, 1405'w/1st ghost reamer,and 2664'w/2nd ghost reamer. Fill pipe every 20 stands. 23:30 00:00 0.50 2,912 3,007 INTRM2 CEMEN-WASH T Wash down f/2912'to 3007', pumping 750 gpm w/1700 psi. PU wt 132k, SO wt 115k, Rot wt 124k, torque 10k off bottom. Prepare to slip and cut drill line. I._ Page 35 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/24/2012 24 hr Summary Slip and cut drill line, service top drive,calibrate MWD block height,wash down f/3007'to 3572'(took 10k while pumping 750 gpm @ 3562'(TOC)@ 0345 hrs), Drill hard cement f/3572'to 3700',time drill to kick off cement plug @ 3700',drill 3700'to 3856',displace to new 9.6 ppg LSND mud,continue to drill 9-7/8" intermediate hole f/3856'to 4981'(3025'TVD). 00:00 01:00 1.00 3,007 3,007 INTRM2 RIGMN1SLPC T Slip and cut 60'of 1-3/8"drill line, service top drive. 01:00 01:45 0.75 3,007 3,007 INTRM2 RIGMNT SVRG T Service top drive,adjust dollys, tighten link tilt ram. top 01:45 02:15 0.50 3,007 3,007 INTRM2 RIGMNTSVRG T Calibrate MWD block height. 02:15 03:45 1.50 3,007 3,562 INTRM2 RIGMNTSVRG T Wash down f/3007'to 3572'.Tagged 1]t_@_ 552'_w/10k weight on bit. Pumping 750 gpm w/1770 psi. 03:45 04:00 0.25 3,562 3,572 INTRM2 CEMEN-REAM T Ream f/3562'to 3572'(At 3572',set 25k WOB--with pumps 750 gpm-no rotary). Pumping 750 gpm w/1850 psi, rotate 50 rpm w/11k ft lbs of torque. Run 5-15k weight on bit. 04:00 05:15 1.25 3,572 3,700 INTRM2 CEMEN"DRLG T Drill hard cement f/3572'to 3700'. Pumping 750 gpm w/1850 psi, rotate 50 rpm w/14-15k ft lbs of torque. Run 10-15k weight on bit. 05:15 09:15 4.00 3,700 3,856 INTRM2 CEMEN-KOST T Time drill to kick off cement plug @ 3700',drill to 3856'(2570'TVD). Actual drilling time 3.23 hrs.Weight on bit 4-10k, Pumping 750 gpm w/ 1660 psi, Rotating 70 rpm w/12.k ft lbs of torque. ECD's 10.38 ppg 09:15 10:00 0.75 3,856 3,856 INTRM2 DRILL CIRC T Displace to new 9.6 ppg LSND mud @ 3856',pumping 615 gpm w/1130 psi. 10:00 10:15 0.25 3,856 3,856 • INTRM2 DRILL OTHR T Clean under shakers in pits. 10:15 12:00 1.75 3,856 3,951 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675)RSS f 3761' to 3951'MD 2611'TVD ADT-.93 hrs---Total hrs on bit 4.16 hrs--- Jar hrs total: 146.86 hrs-- -ECD-10.60 ppg Footage-190' WOB 2-10 k---RPM 140---GPM 750 @ 1440 psi Torque on/off btm.--- 12.5/10.5k ft/lbs String wt: PU 145k SO 123k ROT 132k Page 36 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 3,951 4,981 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f 3951' to 4981'MD 3025'TVD ADT-7.49 hrs---Total hrs on bit 11.65 hrs--- Jar hrs total: 154.35 hrs ---ECD-10.60 ppg Footage-1030' WOB 2-15 k---RPM 140---GPM 750 @ 1440-1830 psi Torque on/off btm.--- 14/12 k ft/lbs String wt: PU 165k SO 124k ROT 140k Pumped(4)30-35 bbl hi vis weighted(11.5ppg)sweeps with 5ppb nut plug @:4045',4360',4655'and 4945'. Increase of 2-2.5 times cuttings back with sweeps. 03/25/2012 Continue to drill 9-7/8"intermediate hole f/4981'to 7152'(3879'TVD)(2171'drilled). 00:00 12:00 12.00 4,981 6,116 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 4981' to 6116'MD 3470'TVD ADT-6.46 hrs---Total hrs on bit 18.11 hrs--- Jar hrs total: 160.81 hrs ---ECD-10.40 to 10.7 ppg Footage- 1135' WOB 5-13 k---RPM 140---GPM 750 @ 1760-2120 psi Torque on/off btm.--- 14-12.5/12-8.5 k ft/lbs String wt: PU 156k SO 144k ROT 150k Pumped(3)30-35 bbl hi vis weighted(11.5ppg)sweeps with 5ppb nut plug @: 5250', 5530',5771'and (1)non weighted nut plug sweep @ 6000'. Increase of 2-2.5 times cuttings back with sweeps. Performed dilution of 20 bbls @ 5380'and 275 bbls @ 6100'. Added lubes to 1%@ 5800'. • Page 37 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 6,116 7,152 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675)RSS f/ 6116' to 7152'MD 3879'TVD ADT-6.72 hrs---Total hrs on bit 24.83 hrs--- Jar hrs total: 167.53 hrs ---ECD-10.68 to 10.32 ppg Footage-1036' WOB 5-20 k---RPM 140 to 180-- -GPM 750 @ 2120-2370 psi Torque on/off btm.--- 12.5-13.5/8.5- 9.5k ft/lbs String wt: PU 163k SO 144k ROT 154k Pumped(1)30-35 bbl hi vis sweeps with 5ppb nut plug @:6590'. Increase of 2 times cuttings back with sweeps. Pumped(2)bit balling sweeps @ 6660', and 6700'.5ppb Nut plug, SAPP,drillzone Performed dilution of 275 bbls @ 6470'and 6880'. Lubes to 1-1/2%@ midnight depth of 7152'. Changing shaker screens on all 3 shakers @ midnight to: 200/200/200/84. 03/26/2012 Change shaker screens,continue to drill 7152'to 9411'(4775'TVD)(2259'drilled). 00:00 01:30 1.50 7,152 7,152 INTRM2 RIGMNT SVRG T Change shaker screens on all three shakers. Change f/270/270/270/270 to 200/200/200/84. Fluid blinding off on the original shaker screens. Circulate/reciprocate 7152'to 7057' at a slow rate while changing screens, pumping 2 bpm w/110 psi.. 01:30 01:45 0.25 7,152 7,152 INTRM2 DRILL SRVY T Survey @ 7152'. 01:45 02:00 0.25 7,152 7,152 INTRM2 DRILL REAM T Backream f/7152 to 7057 at full drilling rate(750 gpm up/720 gpm down)w/2200/2050 psi.Then make a connection. Page 38 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 12:00 10.00 7,152 8,160 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675)RSS f/ 7152' to 8160'MD 4227'TVD ADT-5.15 hrs---Total hrs on bit 29.98 hrs--- Jar hrs total: 172.68 hrs ---ECD-10.57 to 10.46 ppg Footage-1008' WOB 5-20 k---RPM 180---GPM 750 @ 2200-2140 psi Torque on/off btm.--- 13.5-16/11- 12.5k ft/lbs String wt: PU 181k SO 151k ROT 165k Pumped(2)30-35 bbl hi vis(9.6ppg) sweeps with 5ppb nut plug @: 7350',7640'. Increase of 1.5 times cuttings back with sweeps. Performed dilution of 550 bbls @ 7830'. Lubes to 1-1/2%. Changed all three shaker's screens f/200/200/200/84 to 200/200/270/200. 12:00 00:00 12.00 8,160 9,411 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 8160' to 9411'MD 4775'TVD ADT-6.07 hrs---Total hrs on bit 36.05 hrs--- Jar hrs total: 178.75 hrs ---ECD-10.41 to 10.50ppg Footage- ✓ 1251' WOB 10-20 k---RPM 160---GPM 750 @ 2140-2300 psi Torque on/off btm.--- 16-19/12- 13k ft/lbs String wt: PU 194k SO 154k ROT 174k Pumped(3)30-35 bbl hi vis(9.6ppg) sweeps with 5ppb nut plug @: 8376', 8942',and 9411'. Increase of 1.5 times cuttings back with sweeps. Performed dilution of 275 bbls @ 8660'. Lubes to 1-1/2%. 03/27/2012 Continue to drill 9411'to 11830'(5719'TVD)(2419'drilled).Trouble shoot loss of pump pressure. Note:Add screen clean and de foamer(DF-9065)to mud,also repaired mud pump#2(Broke valve spring&incorrectly installed valve guide). Page 39 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 9,411 10,726 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 9411' to 10726'MD 5285'TVD ADT-6.1 hrs---Total hrs on bit 42.15 hrs--- Jar hrs total: 184.85 hrs-- -ECD-10.5 to 10.54 ppg Footage- 1315' WOB 10-20 k---RPM 160---GPM 750 @ 2140-2090 psi Torque on/off btm.--- 19-21/13-14.5-k ft/lbs String wt: PU 210k SO 163k ROT 183k Pumped(1)30-35 bbl hi vis(9.6ppg) sweeps with 5ppb nut plug @:9411' and 10257'. Cuttings back with sweeps: no noticable difference. Performed dilution of 550 bbls @ 9883'. Attempting to get Lubes back to1-1.5to2%. 12:00 22:45 10.75 10,726 11,830 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 10726' to 11830'MD 5719'TVD ADT-6.6 hrs---Total hrs on bit 48.75 hrs--- Jar hrs total: 191.45 hrs-- -ECD-10.6 to 10.4 ppg Footage- 1104' J WOB 15-20 k---RPM 160---GPM 750 @ 2090-1750 psi Torque on/off btm.--- 21-23/14.5-16k ft/lbs String wt: PU 223k SO 166k ROT 192k Performed dilution of 550 bbls @ 10895'and 11414'. Attempting to get Lubes back to 1-1.5 to 2%. 22:45 00:00 1.25 11,830 11,830 INTRM2 DRILL CIRC T Loss of pump pressure while drilling. Trouble shoot surface equipment. Work pipe f/11800 to 11770'. 03/28/2012 Trouble shoot loss of pump pressure, repair#2 mud pump, circulate and perform a 550 bbls mud dilution, continue to directional drill 9-7/8"hole w/Schlumberger rotary steerable f/11830'to 13459'. Drilled 1629' today. Pumped a weighted sweep surf-surf, came back'100 bbls late.Continue to circulate, backreaming 3-4'/minute to clean hole, rotating 160 rpm w/19k ft lbs of torque,pumping 750 gpm w/2340 psi. Depth @ midnight 13176' 00:00 00:30 0.50 11,830 11,830 INTRM2 RIGMNT SVRG T Pre job safety meeting. Service rig while trouble shooting loss of pump pressure while drilling. Add screen clean and de foamer (DF-9065)to mud. Circulate hole w/ #1 mud pump,pumping 98 spm w/ 800 psi. Page 40 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 03:30 3.00 11,830 11,830 INTRM2 RIGMNT RGRP T Trouble shoot mud pump#2. Found broken valve spring. Replaced spring. Placed pump back on line.Still not pumping.Cleaned all suction and discharge screens. Check out pump again,found incorrectly installed valve guide. Put back together. Now it works. Add screen clean and de foamer (DF-9065)to mud.Circulate hole w/ #1 mud pump, pumping 98 spm w/ 800 psi. 03:30 04:00 0.50 11,830 11,830 INTRM2 DRILL CIRC T Performed dilution of 550 bbls @ 11830'. Pumping 750 gpm w/2240 psi. Rotate 120 rpm w/18k ft lbs of torque.Will be attempting to get Lubes back to 2-2.5%. 04:00 12:00 8.00 11,830 12,640 INTRM2 DRILL DDRL T Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 11830' to 12640'MD 6042'TVD ADT-4.51 hrs---Total hrs on bit 53.26 hrs--- Jar hrs total: 195.96 hrs ---ECD-10.4 to 10.55 ppg Footage- 810' WOB 15-23 k---RPM 160---GPM 750 @ 2230-2150 psi Torque on/off btm.--- 22-24/16-16.5k ft/lbs String wt: PU 236k SO 170k ROT 202k Performed a dilution of 275 bbls @ 12530'. Attempting to get Lubes backto2to2.5% . 12:00 21:45 9.75 12,640 13,459 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 12640' to 13459'MD 6341'TVD ADT-5.74 hrs---Total hrs on bit 59 hrs--- Jar hrs total:201.7 hrs-- -ECD-10.4 to 10.46 ppg Footage- 819' WOB 15-24 k---RPM 160---GPM 750 @ 2150-2350 psi Torque on/off btm.--- 23.5-24/16.5-18.5k ft/lbs String wt: PU 252k SO 169k ROT 205k Performed a dilution of 275 bbls @ 13280'. Attempting to get Lubes back to2to2.5%. 21:45 22:15 0.50 13,459 13,459 INTRM2 DRILL DDRL P Circulate Hi vis weighted nut plug sweep out of the hole.90-100 bbls late. Pumping 750 gpm w/2340 psi, rotate 160 rpm w/19k ft lbs of torque. Recip f/13459'to 13365'. 22:15 22:30 0.25 13,459 13,459 INTRM2 DRILL SRVY P Obtain torque and drag.Obtain survey. Page 41 of 72 Time Logs Date From To Dur S. Death E. Deoth Phase Code Subcode T Comment 22:30 00:00 1.50 13,459 13,176 INTRM2 DRILL CIRC P Circulate 3 BU. Pumping 750 gpm w/ 2340 psi, rotate 160 rpm w/19k ft lbs of torque. Backream f/13459', pulling 3-4'/minute,setting back a stand every 30 minutes. Note: Ricky w/WWT checking the super sliders while pulling out of the hole. 12 stands were drilled with. 03/29/2012 Continue to circ,backreaming to clean hole f/13176'to 12894', POOH on elevators f/12894'to 11480',Circ& dilute 550 bbls of mud while BR f/11480'to 11291', monitor well, pump dry job, POOH on elevators f/11291' to 5629'. 50k overpull @ 5629'. Backream f/5642'to 5453',circ 1.75 BU,attempt to POOH on elevators, swabbing,Continue to backream f/5453'to 3384'. MU Baker 10-3/4"Model"EA"storm packer, RIH,set center of element @ 102.71'and w/bit @ 3590.76', release, POOH,fill stack w/water,test packer to 300 psi f/10 minutes flat line-OK. Charted test. 00:00 01:45 1.75 13,176 12,894 INTRM2 DRILL CIRC P Continue to circulate,backreaming 3-4'/minute to clean hole, rotating 160 rpm w/19k ft lbs of torque, pumping 750 gpm w/2340 psi from 13176'to 12894', 01:45 02:00 0.25 12,894 12,894 INTRM2 DRILL OWFF P Monitor well-static.. Blow down the top drive. 02:00 03:45 1.75 12,894 11,480 INTRM2 DRILL WPRT P POOH on elevators&trip tank f/ 12894'to 11480'. Hole taking prper fill. 03:45 05:30 1.75 11,480 11,291 INTRM2 DRILL CIRC P Circulate&dilute 550 bbls of mud while BR f/11480'to 11291'. Pumping 750 gpm w/2040 psi, rotate120 rpm w/16-17k ft lbs of torque. Note: Mud MBT was 16.5 prior,after 12 MBT. 05:30 05:45 0.25 11,291 11,291 INTRM2 DRILL OWFF P Monitor well-static. 05:45 06:00 0.25 11,291 11,291 INTRM2 DRILL CIRC P Pump dry job. Blow down the top drive. 06:00 12:15 6.25 11,291 5,629 INTRM2 DRILL WPRT P POOH on elevators f/11291'to 5629'.Wiped through tight spots @ 8022',7497',7434',7361'w/20-40K over. Made several attempts to pass 5629'pulling 50K over, unable. 12:15 13:45 1.50 5,642 5,453 INTRM2 DRILL REAM P Backream from 5642'to 5453'-120 rpm @ 9-10K torque-750 gpm @ 1790 psi encountered tight hole @ 5269'and 5565'-Circulated 1.75 X BU 710 bbls)while reaming- observed a mild increase in cuttings at first BU-flow check well,static- blow down top drive-attempted to pull pipe on elevators-hole swabbing. Page 42 of 72 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 13:45 15:45 2.00 5,453 4,981 INTRM2 DRILL REAM P Isolate pumps to pit#5-Continue to Backream from 5453'to 4981'-120 rpm @ 10-11K torque/750 gpm @ 1760 psi -no problems while backreaming-flow check well,static -blow down top drive-attempted to pull pipe on elevators-hole swabbing. 15:45 21:00 5.25 4,981 3,384 INTRM2 DRILL REAM P Continue to Backream from 4981'to 3384'. Pumped a 35 bbl weighted 11.6 ppg hi vis nut plug(6ppb)sweep while pulling f/3666'-3572'(observed 1.5 to 2 times increase in cuttings at shakers), pumped a hi vis nut plug(6 ppb)sweep while pulling 3468'-3385' (observed 1.5 to 2 times increase in cuttings at the shakers). 21:00 21:30 0.50 3,384 3,450 INTRM2 DRILL OTHR P Monitor well-static.Check top drive torque against rig tongs and iron roughneck. 21:30 21:45 0.25 3,450 3,478 INTRM2 DRILL OWFF P Blow down the top drive.Monitor well-static. 21:45 22:00 0.25 3,478 3,478 INTRM2 WHDBO SFTY P Pre job safety meeting w/Baker Oil Tools rep on Make up&setting 10-3/4"storm packer. 22:00 23:00 1.00 3,478 3,591 INTRM2 WHDBO PULD P Make up 10-3/4"Model"EA" retrievamatic storm packer assembly. Run in hole and set(left hand rotation),with 88.83'in on stand#18.Top of tools @ 89.57', Center of element @ 102.71', Bottom of packer assembly @ 107.59'. Bit depth 3590.76'. PU wt 125-130k, SO wt 120K. Block wt 72k. 23:00 23:30 0.50 3,591 0 INTRM2 WHDBO PULD P Release from safety joint,turning the stand 10 turns to the right. Pick up, break off running tool,stand back stand#18. 23:30 00:00 0.50 0 0 INTRM2 WHDBO DHEQ P Fill stack with water,test 10-3/4" storm packer w/rig test pump to 300 psi f/10 minutes flat line. Good test. Charted test. 03/30/2012 Rig up,Test BOPE,slip and cut drill line, retrieve storm packer @'90',trip in hole f/3478'to 11197', Circ/Ream f/11197'to 11386'(mud out of balance), RIH to 13271',precautionary ream f/13271'to TD @ 13459',directional drill f/13459'to 13516'@ midnight. 00:00 01:00 1.00 0 0 INTRM2 WHDBO OTHR P RU to pull wear bushing-unable to pull w/tugger-latch elevators-Pull wear bushing loose w/2 k bump- Set lower test plug with tugger. 01:00 01:45 0.75 0 0 INTRM2 WHDBO BOPE P RU to test BOPE-fill stack&choke manifold w/water. Page43of72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 06:00 4.25 0 0 INTRM2 WHDBO BOPE P Test BOPE as follows: annular to 250&2500 psi-Upper pipe rams, choke manifold valves, choke&kill line manual&HCR valves-Floor safety&dart valves-Auto&manual IBOP valves-Lower pipes to 250& 3500 psi-Performed accumulator recovery test-LD test jt. (5")-tested blind rams to 250&3500 psi- Performed draw down test on super &manual chokes to 1500 psi- Witnessing of test waived by Matt Herrera w/AOGCC. Note: Electrician tested gas alarms. Blow down lines-Pull&LD test jt. 06:00 08:00 2.00 0 0 INTRM2 RIGMNT SLPC P Slip and cut 60'of drilling line-adjust drawworks brakes and serviced top drive. 08:00 09:15 1.25 0 0 INTRM2 WHDBO OTHR P MU running tool and attempt to install wear bushing with tugger- stopped 1'high-pull and inspect wear bushing-dressed small lips from bottom of wear bushing-rerun wear bushing,stopped at same spot -seated wear bushing with 5K assistance from top drive 09:15 11:00 1.75 0 3,478 INTRM2 WHDBO PULD P PJSM-Make up 10-3/4"Model"EA" storm packer retrieving tool on stand #18 of drill pipe-RIH and install and close TIW valve on top of stand- engage storm valve @'90'per procedure-slowly open TIW valve to check for trapped pressure-no pressure observed-pick up string 3" to open equalizer valve-check annulus for flow-no flow-pull up 2' and allow element to relax for 5 minutes-monitor well,static-slack off and lay down TIW valve and handling pup-POOH slowly-set back stand#18-Lay down storm valve 2nd handling pup and storm packer-monitor well on trip tank- static. 11:00 12:00 1.00 3,478 3,478 INTRM2 DRILL OTHR P Move Top Drive per MWD hand request to obtain drawworks en coder data after slipping drilling line- Perform block height recalibration procedure for MD Totco system- Obtain free torque data points with Top Drive per Engineering request 12:00 19:30 7.50 3,478 11,197 INTRM2 DRILL WPRT P Trip in the hole f/3478'to 11197'. Fill pipe every 20 stands.Obtain PU and SO wt's every 20 stands. Page 44of72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 11,197 11,481 INTRM2 DRILL WASH P Wash f/11197'to 11386'. Pumping 436 gpm w/1080 psi,510 gpm w/ 1380 psi, 550 gpm w/1530 psi,625 gpm w/1910 psi. Run a stand f/ 11386'to 11481'. 20:15 20:30 0.25 11,481 11,481 INTRM2 DRILL OTHR P Blow down the top drive. 20:30 22:00 1.50 11,481 13,271 INTRM2 DRILL WPRT P Trip in the hole f/11481'to 13271'. Fill pipe every 20 stands. Obtain PU and SO wt's every 20 stands. 22:00 22:15 0.25 13,271 13,271 INTRM2 DRILL OWFF P Monitor well-static. 22:15 23:15 1.00 13,271 13,459 INTRM2 DRILL REAM P Precautionary wash and ream f/ 13271'to 13459'.Stage pumps up f/ 500 gpm w/1460-1510 psi to final of 750 gpm w/2490-2560 psi. ECD's 10.67. Rotate 120 rpm w/18.5 k ft lbs off bottom. Performed a dilution of 275 bbls @ 13365'to 13459'. New mud was added to pits 2, 3,and 4 while tripping. 23:15 00:00 0.75 13,459 13,516 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 13459' to 13516'MD 6362'TVD ADT-.51 hrs---Total hrs on bit 59.51 hrs--- Jar hrs total:202.21 hrs-- -ECD-10.83 to 10.75 ppg Footage- 57' WOB 15-22 k---RPM 160---GPM 750 @ 2630-2800 psi Torque on/off btm.--- 24/18.5k ft/lbs String wt: PU 255k SO 163k ROT 195k Attempting to get Lubes back to 2 to2.5% . 03/31/2012 Directional drill 9-7/8"hole f/13516'to 14959', change shaker screens,continue to directional drill f/14959'to 15053', change shaker screens, continue to drill f/15053'to 15085'(6722'TVD). 00:00 12:00 12.00 13,516 14,407 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 13516' to 14407'MD 6607'TVD ADT-7.03 hrs---Total hrs on bit 66.54 hrs--- Jar hrs total:209.24 hrs ---ECD- 10.75 to 11.4 ppg Footage- 891' WOB 15-22 k---RPM 160---GPM 750 @ 3350 psi Torque on/off btm.--- 25/18k ft/lbs String wt: PU 275k SO 165k ROT 206k Made glycol dilution and weighted mud system f/9.6 ppg to 10.5 ppg by 13850'. Attempting to get Lubes up to 4.5 to5%. Pumped a 35 bbl sweep w/35 ppb Alpine beads @ 14400'. Page 45 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 14,407 14,895 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 114407' to 14895'MD 6694'TVD ADT-4.29 hrs---Total hrs on bit 70.83 hrs--- Jar hrs total:213.53 hrs ---ECD-11.59 ppg Footage-488' WOB 18-25 k---RPM 160---GPM 750 @ 3350-3650 psi Torque on/off btm.--- 25-26/19k ft/lbs String wt: PU 290 k SO 162 k ROT 210 k Lubes up to 5 to 5.5%. Pumped a 35 bbl sweep w/35 ppb Alpine beads @ 14540'. 18:00 18:45 0.75 14,895 14,959 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 114895' to 14959'MD 6703.5' TVD ADT-.53 hrs---Total hrs on bit 71.36 hrs--- Jar hrs total:214.06 hrs-- -ECD-11.43 ppg Footage-64' WOB 22 k---RPM 160---GPM 750 @ 3540 psi Torque on/off btm.--- 27/20k ft/lbs String wt: PU 290 k SO 162 k ROT 210k Lubes up to 5.5% . Pumped a 35 bbl sweep w/35 ppb Alpine beads @ 14883'. 18:45 20:00 1.25 14,959 14,959 INTRM2 RIGMNTOTHR T Shut down to change shaker / screens.Went f/200/200/270/84 to #1:165/165/165/165,#2: 200/200/200/165, #3: 200/200/165/84. Circ, pumping 126 gpm w/340 psi, while changing screens.Changing these screens is not rig repair,trying to keep mud on the shakers while pumping 750 gpm. 20:00 21:45 1.75 14,959 15,053 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 14959' to 15053'MD 6717'TVD ADT-.96 hrs---Total hrs on bit 72.32 hrs--- Jar hrs total: 215.02 hrs-- -ECD-11.3 ppg Footage-94' WOB 22 k---RPM 160---GPM 750 @ 3520-3490 psi Torque on/off btm.--- 27.5/20k ft/lbs String wt: PU 285 k SO 155 k ROT 210k Lubes up to 5.5-6%. Page 46 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 23:15 1.50 15,053 15,053 INTRM2 RIGMNT OTHR T Shut down to change shaker screens. Stand back stand#141. Went f/ #1:165/165/165/165 to 165/165/84/84,#2: 200/200/200/165 to 165/165/84/84, #3:200/200/165/84 to 165/165/84/84. Circ, pumping 126 gpm w/340 psi, while changing screens.Changing these screens is not rig repair,trying to keep mud on the shakers while 'pumping 750 gpm. Pump over 'shakers and bring 180 bbls of mud back from the ball mill to the rig. 23:15 23:30 0.25 15,053 15,053 INTRM2 DRILL TRIP P Make a top drive connection w/stand #141. 23:30 00:00 0.50 15,053 15,085 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 15053' to 15085'MD 6722'TVD ADT-.36 hrs---Total hrs on bit 72.68 hrs--- Jar hrs total:215.38 hrs-- -ECD-11.3 ppg Footage-32' WOB 22 k---RPM 160---GPM 750 @ 3640 psi Torque on/off btm.--- 27.5/20k ft/lbs String wt: PU 285 k SO 155 k 'ROT 210 k Lubes up to 5.5-6%. 04/01/2012 Directional drill 9-7/8"hole f/15085'to 15258'TD(6747.16'TVD), POOH/circ/rotate f/15258'to 14111', RIH to 15258', CBU&weight up f/10.5 ppg to 11 ppg,Stand back stands f/15258'to 15052', Ream back to 15258', L/D single, monitor well-static,Spot casing running pill f/15258'to 14105', BD top drive, monitor well-slight drop, RIH on elevators f/14105'to 14460', Pump out f/14460'to 13451'(Tight spot @ 14348'-25k over-wipe out),continue to POOH pumping to 13451', BD top drive,monitor well-slight loss, POOH on elevators f/ 13451'to 10914-monitor on trip tank. 00:00 02:45 2.75 15,085 15,258 INTRM2 DRILL DDRL P Drilled 9 7/8"hole w/Schlumberger Power Drive(Xceed 675) RSS f/ 15085' to 15258'MD 6747.16' TVD ADT-1.62 hrs---Total hrs on bit 74.3 hrs--- Jar hrs total:217 hrs---ECD- 11.3 ppg Footage-178' WOB 22 k---RPM 160---GPM 750 @ 3640 psi Torque on/off btm.--- 27.5/21k ft/lbs String wt: PU 290 k SO 155 k ROT 205 k Lubes up to 5.5-6%. Obtain slow pump rates and final surveys. 02:45 08:30 5.75 15,258 14,438 INTRM2 CASING CIRC P CBU x5 while POOH/circ/rotate f/ 15258'to 14438'. Pumping 750 gpm w/3500 to 3475 psi, rotate 140 rpm w/22500 to 24 ft lbs of torque. ECD's 11.29 to 11 ppg. Pulling speed 3-4'/minute. Page 47 of 72 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 08:30 09:30 1.00 14,438 14,111 INTRM2 CASING WPRT P Circ/Rotate/POOH f/14438'to 14111'. Pumping 750 gpm w/3410 psi. Rotate 120 rpm w/21k ft lbs of torque. 09:30 09:45 0.25 14,111 14,111 INTRM2CASINGOWFF P Monitorwell-static. 09:45 10:30 0.75 14,111 15,258 INTRM2 CASING WPRT P Trip in the hole f/14111'to 15258'. PU wt 290k,SO wt 160k. 10:30 10:45 0.25 15,258 15,258 INTRM2 CASING OWFF P Monitor well-static. 10:45 12:00 1.25 15,258 15,258 INTRM2 CASING CIRC P CBU&weight up f/10.5 ppg to 11 ppg. Set back a stand every hour. Pumping 750 gpm w/3510 psi, rotate 140 rpm w/23k ft lbs of torque off bottom. Rotating weight 210k. 12:00 13:45 1.75 15,258 15,052 INTRM2 CASING CIRC P CBU&weight up f/10.5 ppg to 11 ppg. Set back a stand every hour f/ 15258'to 15052'. Pumping 725 gpm w/3380 psi, rotate 140 rpm w/24k ft lbs of torque off bottom. Rotating weight 210k. 13:45 15:00 1.25 15,052 15,258 INTRM2 CASING CIRC P CBU&weight up f/10.5 ppg to 11 ppg. Reaming down f/15052'to 15258'. Pumping 663 gpm w/3200 psi, rotate 140 rpm w/22.5k ft lbs of torque off bottom. Rotating weight 210k. Performed a dilution w/340 bbls of glydril mud, 11ppg,while weighting up to 11 ppg. 15:00 15:15 0.25 15,258 15,242 INTRM2 CASING OWFF P Lay down a single to 15242'. Monitor well-static. 15:15 15:45 0.50 15,242 15,242 INTRM2 CASING CIRC P Load casing running pill in the drill pipe. PU wt 265k. Pumping 663 gpm w/3200 psi. 15:45 17:45 2.00 15,242 14,105 INTRM2 CASING TRIP P Pump and POOH spotting casing,, running pill in open hole f/15242'to 14105'. Pumping 2.5 bpm w/280 psi, pulling 20'/min.Tight spots(25k over) @ 15190', 14999', 14873', 14405', and 14340.Wiped out tight spots, no problems on slack off,able to work until PU wt normal @ 260k. Note: Casing running pill: additional 3%glydril,2%lube 776, 5 ppb Sack Black, 5 ppb Safecarb 20, 5 ppb Safe Garb 40 and 5 ppb Alpine Beads. Note:#1 and#2 shaker screens were changed to 200/200/84/84.#3 is still 165/165/84/84. 17:45 18:00 0.25 14,105 14,105 INTRM2 CASING OTHR P Blow down the top drive. 18:00 18:15 0.25 14,105 14,460 INTRM2 CASING TRIP P RIH f/14105'to 14460'to wipe and check out some of the previous tight spots. PU 265k,SO 155-65k. Page 48 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 20:45 2.50 14,460 13,451 INTRM2 CASING TRIP P Pump and POOH 14460'to 13451'. Pumping 2.5 bpm w/280 psi, pulling 20'/min.Tight spot(25k over)@ 14340'.Wiped out tight spot, no problems on slack off,able to work until PU wt normal @ 260-265k. 20:45 21:00 0.25 13,451 13,451 INTRM2 CASING OTHR P Blow down the top drive. 21:00 00:00 3.00 13,451 10,914 1INTRM2 CASING TRIP P POOH wet on elevators and trip tank, pulling 20-35'/minute f/13451'to 10914'.At 10914': PU wt 225k,SO wt 150k. 04/02/2012 POOH on elevators f/10914'to 10137'-monitor on trip tank. RIH to 10257', Pump out f/10257'to 10137'(35k over). Backream f/10160'to 10069', RIH 2 stands to 10351', POOH on trip tank f/10351'to 8364'w/ numerous overpulls-wiped out, RIH f/8364'to 8564', backr ream f/8564'to 7810', POOH on elvators f/7810' to 4050', packed off @ 4050',con't BR slow to 3794'@ midnight. 00:00 00:45 0.75 10,914 10,137 INTRM2 CASING TRIP P Continue POOH wet on elevators and trip tank, pulling 25'/minute avg f/ 10914'to 10137'. Pulled tight, attempt to work through with 55K over. : PU wt 220k,SO wt 150k at 10162' 00:45 01:00 0.25 10,137 10,257 INTRM2 CASING TRIP P Flow check, RIH one stand to 10257'. 01:00 01:30 0.50 10,257 10,137 INTRM2 CASING TRIP P Pump out of hole from 10257'to 10137', pulled 35K over at 10137'. 01:30 02:45 1.25 10,137 10,137 INTRM2 CASING TRIP P Backream tight spot with increased torque,continue ream stand f/10160' to 10069',while CBU at 500 gpm, 1580 psi, 140 rpm at 22K torque. Run in to stand down at 10160' with-out rotary ok. 02:45 03:15 0.50 10,137 10,351 INTRM2 CASING TRIP P Flow check static, RIH two stands from 10162'to 10351'. 03:15 06:00 2.75 10,351 8,364 INTRM2 CASING TRIP P Flow check static, POOH on trip tank wet from 10351'to 8364'. Worked thru tight spots at 10066', 10000',9991',9985',9929',9196', 8542', 8535'with-out problem, no excess drag when ran down thru. Pulled to 8364'where 50K excess drag was observed and could not work thru. PU 215K, SO 150K. 06:00 06:15 0.25 8,364 8,564 INTRM2 CASING TRIP P RIH two stands from 8364'to 8564'to get below tight spots pulled through. No excess drag observed. PU 190K, SO 140K. 06:15 08:45 2.50 8,564 7,810 INTRM2 CASING TRIP P Flow check static, BROOH from 8564'to 7810'increasing flow rate from 500 gpm 1410 psi to 750 gpm at 2830 psi, 130 rpm with torque increasing to 20K by 8175'then diminishing to 15K by 8000'to 7810'. 08:45 09:30 0.75 7,810 7,406 INTRM2 CASING TRIP P Flow check static, POOH on trip tank wet from 7810'to 7406'where 55K over pull was observed. PU 185K,SO 135K. Page 49 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 7,406 6,396 INTRM2 CASING TRIP P Flow check static, BROOH from 7406'to 6396'w/flow rate 750 gpm at 2830-2730 psi, 130 rpm with 15 to 112.5K ft lbs of torque. 12:00 17:30 5.50 6,396 4,050 INTRM2 CASING TRIP P BROOH from 6396'to 4050'w/flow rate 750 gpm at 2730-2550 psi, 130 rpm with 12.5-10.5K ft lbs of torque. 17:30 17:45 0.25 4,050 4,050 INTRM2 CASING TRIP P Packed off while back reaming @ 4050'. Flow check,slight flow slowed down in 10 minutes. 17:45 00:00 6.25 4,050 3,794 INTRM2 CASING TRIP P BROOH from 4050'to 3794'w/flow rate 750 gpm at 2550-2300 psi, 130 rpm with 10.5-8kK ft lbs of torque, increased rpm to 140 w/10k ft lbs, @ 4055'increased rpm to 180 w/ 10.5k ft lbs of torque.. 04/03/2012 BROOH f/3794' 1206'(pumping nut plug sweeps @ 3572', 3291', 1871',&1301') POOH on TT f/1206'-LD BHA-Change upper pipe rams&test for casing run-RU to run casing-Ran 7 5/8"casing to 3819'- Establish Circ @ 3 bbls/min @ 150 psi 00:00 00:45 0.75 3,794 3,572 INTRM2 CASING TRIP P Flow check static, BROOH from 3794'to 3572'w/flow rate 750 gpm at 2270-2310 psi, 170 rpm with 9.5 to 10.5K ft lbs of torque. 00:45 02:00 1.25 3,572 3,572 INTRM2 CASING CIRC P Flow check well,static-Pumped 40 bbls of 13.0 ppg sweep w/nutplug- circulated until shakers cleaned up- observed a lot of packed cuttings 3/4"to 3"diameter"patties"back- 750 gpm/2300 psi/170 rpm @ 8- 9.6 K ft/Ibs 02:00 02:30 0.50 3,572 3,291 INTRM2 CASING TRIP P Flow check static, BROOH from 3572'to 3291' - 750 gpm at 2250-2220 psi, 130 rpm with 9.5 to 10.5K ft lbs of torque. 02:30 03:00 0.50 3,291 3,291 INTRM2 CASING CIRC P Pumped 37 bbls of 13.0 ppg sweep w/nutplug-circulated until shakers cleaned up-still a lot of packed cuttings 3/4"to 3"diameter"patties" back- 750 gpm/2180-2230 psi/ 145 rpm @ 8.3-7.5 K ft/lbs 03:00 05:30 2.50 3,291 1,871 INTRM2 CASING TRIP P Flow check static, BROOH from 3291'to 1871' - 800 gpm at 2350-2210 psi, 150 rpm with 7.2 to 5.5K ft lbs of torque. Rot.PUW 115K 05:30 06:00 0.50 1,871 1,871 INTRM2 CASING CIRC P Pumped 41 bbls of 13.0 ppg sweep w/nutplug-circulated until shakers cleaned up-fair amount of packed cuttings 3/4"to 2"diameter"patties" back- 800 gpm/2150 psi/140 rpm @ 5 K ft/lbs 06:00 07:15 1.25 1,871 1,206 INTRM2 CASING TRIP P BROOH from 1871'to 1206' - 800 gpm at 2140 psi, 120 rpm with 4.8 to 3.8K ft lbs of torque. Rot.PUW 108K -Pumped 37 bbls 13.0 ppg sweep w/ nutplug on last stand reamed-very small amount of cutting back with sweep Page 50 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:15 1.00 1,206 176 INTRM2 CASING TRIP P Flow check well,static-Blow down top drive-POOH on elevators from 1206'to 176'-stood back hwdp 08:15 09:45 1.50 176 0 INTRM2 CASING PULD P PJSM-POOH-Laid down flex collars and BHA#5 componets-no balling on string tools or bit. 09:45 10:30 0.75 0 0 INTRM2 CASING OTHR P Clear BHA tools from rig floor- address housekeeping on rig floor 10:30 11:00 0.50 0 0 INTRM2 WHDBO SEQP P PJSM-Mu retrieving tool and pull wear ring from wellhead with tugger 11:00 13:00 2.00 0 0 INTRM2 WHDBO OTHR P PJSM-Changed top pipe rams to 7 5/8" 13:00 14:15 1.25 0 0 INTRM2 WHDBO BOPE P Set lower test plug with test joint- test 7 5/8"rams to 250/3500 psi- Pulled test plug and lay down test joint-install thin wall wear ring(10.5" ID)Lay down running tool 14:15 14:30 0.25 0 0 INTRM2 CASING SFTY P PJSm on rigging up to run casing 14:30 16:45 2.25 0 0 INTRM2 CASING RURD P Rig up to run 7 5/8"casing-MU fill up tool-elevators&spider-RU ' casing tongs 16:45 17:00 0.25 0 0 INTRM2 CASING SFTY P Held pre job safety and operation �IN� meeting on running casing L K 17:00 23:45 6.75 0 3,819 INTRM2 CASING RNCS P Ran 7-5/8"29.7#L-80 BTCM casing as follows: Float shoe(Ray Oil Tools silver bullet)2 jts csg-Float collar(Halliburton Super Seal w/ bypass baffle)-1 jt.csg-Baffle collar (Halliburton) 1 jt.csg to 176'(shoe track made up w/BakerLoc-fill pipe &circulated to check floats)-86 jts csg to 3819'(90 jts total in hole)- Installed centralizers on first 72 jts.( 1 straight blade on shoe jt&71 Hydroform) PU wt. 142 SO wt. 126 23:45 00:00 0.25 3,819 3,819 INTRM2 CASING CIRC P Establish circ @ 3 bbls/min @ 150 psi 04/04/2012 Ran 7 5/8"csg-13,045'(307 jts total in hole) Circ&condition every 3,000' 00:00 00:30 0.50 3,819 3,819 INTRM2 CASING CIRC P Continue to condition mud @ 3819'- PUW 142K SOW 126K FCP 6.0 bpm/230 psi 00:30 01:30 1.00 3,819 3,819 INTRM2 CASING CIRC P Pumped 35 bbls sweep with Steel Lube surface to surface-6 bpm/ 240 psi-PU wt. 142 SO wt. 126 before pill-observed no change in PU&SO wt. after pill 01:30 07:45 6.25 3,819 7,001 INTRM2 CASING RNCS P Ran 7-5/8"29.7#L-80 BTCM casing from 3819'to 7001'(165 jts total in hole) SOW 158K Installed Halliburton Stage tool on top of jt./ 163 Page 51 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:45 1.00 7,001 7,001 INTRM2 CASING CIRC P Circulate and condition mud-ICP 3.5 bpm/230 psi FCP 6.0 bpm/340 psi Pumps on PUW 190K SOW 145K Mud wt. in/out 11.0 ppg/11.05 ppg 08:45 15:00 6.25 7,001 10,025 INTRM2 CASING RNCS P Ran 7-5/8"29.7#L-80 BTCM casing from 7001'to 10025'(236 jts total in hole) SOW 155K 15:00 17:30 2.50 10,025 10,025 INTRM2 CASING CIRC P Circulate and condition mud-ICP 2.5 bpm/240 psi FCP 6.0 bpm/ 320 psi Pumps on PUW 240/245 SOW 150/155K Mud wt. in/out 11.0 ppg/11.05 ppg 17:30 23:30 6.00 10,025 13,045 INTRM2 CASING RNCS P Ran 7-5/8"29.7#L-80 BTCM casing from 10025'to 13045'(307 jts total in hole) SOW 165K 23:30 00:00 0.50 13,045 13,045 INTRM2 CASING CIRC P Circulate and condition mud-ICP 4.5 bpm/400psi FCP 6.0 bpm/ 500 psi Pumps on PUW 315/345 SOW 150/165K Mud wt. in/out 11.0 ppg/11.0 ppg 04/05/2012 Circ&condition mud @ 13045'-Cont. RIH w/7 5/8"casing f/13,045'to 14,835'-washed casing down f/ 14,835'to 15,242'-RD csg equip./RU cmt head-Circ for cmt job-Pumped 1 ast stage cmtiob-,_UV9C- Opened stage collar-Pumped 2nd stage cmt job 00:00 02:45 2.75 13,045 13,045 INTRM2 CASING CIRC P Continue to Circulate and condition mud- FCP 6.0 bpm/480 psi Pumps on PUW 315 SOW 165K Mud wt. in/out 11.0 ppg/11.15 ppg 02:45 07:00 4.25 13,045 14,835 INTRM2 CASING RNCS P Ran 7-5/8"29.7#L-80 BTCM casing from 13045'to 14835'(350 jts total in hole) SOW 160K-encountered tight spot at 14835'-lost 25K SOW 07:00 11:00 4.00 14,835 15,205 INTRM2 CASING RNCS P Establish circulation 3.0 bpm/460 psi-Worked pipe and washed down through tight hole from 14,835'to 15205'-free pipe SOW 150/155K- washing to bottom SOW intermittent at 125-100K-PUW-350K-once hole was wiper SOW stayed- 150K -increased pump rate to 4 bpm/500 psi from 14,950' 11:00 11:30 0.50 15,205 15,242 INTRM2 CASING RNCS P MU FMC fluted hanger and landing joint-wash down from 15,205'to 15242'-4.0 bpm/550 psi-land hanger in wellhead 11:30 12:15 0.75 15,242 15,242 INTRM2 CEMEN-RURD P Lay down fill up tool-blow down top drive MU cement head and lines 12:15 16:00 3.75 15,242 15,242 INTRM2 CEMEN-CIRC P Establish circulation- P Staged pumps 9 up to 6 bpm-Reciprocate casing- condition mud for cementing-PUW 305K SOW 165K-Mud wt. in 11.0 ppg Mud wt.out 11.7-11.25 ppg- FCP 6.1 bpm/580 psi-total volume pumped 1060 bbls-Held PJSM with Rig Team-had full returns while circulating Page 52 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 15,242 15,242 INTRM2 CEMEN-PUCM P Line up to Cementers-Pump 1st Stage Cement as Follows: Pump 3 bbls CW 100-Pressure Test 54- Surface Lines t/3500 psi-Pump 40 bbls 8.4 PPG CW 100 @ 5 BPM/ 451 Psi-Pump 36 Bbls 12.5 PPG Mud Push @ 5.6 BPM/611 Psi- Dropped bottom plug with last 2 bbls of MudPush(38 bbls total)Bled off lines-floats holding-Load top plug in cement head-Pump 47.7 BBIs (230 sxs) 15.8 PPG Class G Cement w/Additives-—6.3 bpm/657 psi- Dropped top plug-Cementers pumped 10 bbls of fresh water-full returns throughout 16:30 18:15 1.75 15,242 15,242 INTRM2 CEMEN-DISP P Switch to rig pumps-Displaced cement with 11.0 ppg mud @ 7 bpm f/510 to 650 psi-slowed pumps @ 667 bbls away to 3.5 bbls/min @ 350 psi for last 21 bbls of displacement- total displacement 688 bbls-didn't bump plug-Shut in cement head- CIP @ 1815 hrs.-Fjj[returns._ through out job_Continued to reciprocate until last 20 bbls of displacement PU wt 310 SO wt 155 18:15 22:30 4.25 15,242 15,242 INTRM2 CEMEN-WOC T Wait on cement-To pressure up to open stage collar 22:30 22:45 0.25 15,242 15,242 INTRM2 CEMEN-OTHR P Open valve on cement head-bleed -off pressure< 100 psi-Load closing J plug for 2nd stage-Pressure up on (✓ casing to 3310 psi-opened stage 0 collar oa 22:45 23:15 0.50 15,242 15,242 INTRM2 CEMEN CIRC P Circ btms up from 8327'(stage collar)@ 7 bbls/min @ 420 psi- Mud wt 11.0n&out C 4'` PP9 i 7 Held pre job for 2nd stage cmt job 23:15 00:00 0.75 15,242 15,242 INTRM2 CEMEN-PUCM P Pumped 2nd stage cement job as follows: Pumped 30 bbls CW-100 @ co' 5 bbls/min @ 200 psi-Mixed& pumped 30 bbls-12.5 ppg Mud Push @ 4 bbls/min @ 300 psi-Mixed& pumped 57 bbls(280 sks) 15.8 ppg Class G cement w/additives @ 4.5 bbls/min @ 250 psi-Dropped tj(. closing plug w/10 bbls water f/ Dowell 661- 04/06/2012 Displace cmt on 2nd stage cmt job-Closed stage collar-RD casing&cmt.equipment-RU&LD 5"DP f/ derrick-Change top pipe rams-Change saver sub in TD-Set test p[ug Page 53 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 15,242 15,242 INTRM2 CEMEN-DISP P Displaced cement w/378.8 bbls of 11.0 ppg LSND mud @ 7 bbls/min @ 340 psi-Slowed pumps to 3.5 bbls/min @ 240 psi for last 26.8 bbls..-Bumped plug w/750 psi- Held pressur for 2 mins.-pressured up to 1600 psi to close stage collar- Held pressure for 2 mins.-Bleed off pressure-opened bleeder valve on cement head to confirm stage collar was closed-OK-CIP @ 0056 hrs.- Full retunrs throught out job 01:15 01:45 0.50 0 0 INTRM2 CEMEN-RURD P PJSM-Blow down lines-RD spider &elevators-RD cement head-LD landing jt. 01:45 02:30 0.75 0 0 INTRM2 CEMEN-OTHRP PJSM-Pulled thin wall wearb ushing (top of wear bushing damaged barley able to get J'ed into w/pulling tool) Set 7 5/8"pack-off&test to 5000 psi for 10 mins. 02:30 03:00 0.50 0 0 INTRM2 CEMEN"OTHR P Clean&clear rig floor of equipment (casing spider&elevators)Removed long bails f/top drive and sent down f/rig floor 03:00 03:30 0.50 0 0 INTRM2 CEMEN"OTHR P PJSM-Install drilling bails&PU 5" drill pipe elevators 03:30 05:15 1.75 0 0 INTRM2 CEMEN"PULD P PJSM-LD 5"drill pipe f/derrick via mouse hole -Laid down 12 stds HWDP&5 stds 5"DP 05:15 05:45 0.50 0 0 INTRM2 CEMEN-SVRG P Service rig 05:45 12:00 6.25 0 0 INTRM2 CEMEN"PULD P Cont.to LD 5"DP f/derrick via mouse hole-laid down 57stds 12:00 21:15 9.25 0 0 INTRM2 CEMEN"PULD P PJSM-Cont. LD 5"drill pipe f/ derrick via mouse hole 21:15 23:30 2.25 0 0 INTRM2 WHDBO OTHR P PJSM-Change top rams f/7 5/8"to 3 1/2"x 6"VBR-Chnage out TD saver sub f/4 1/2 IF to 4"XT-39 23:30 00:00 0.50 0 0 INTRM2 WHDBO OTHR P PSJM-House keeping on rig floor- Set test plug 34/07/2012 Test BOPE-Std back 11 std HWDP&5 Stds DP-MU CO BHA-RIH to 8205'(PU pipe f/shed)Test csg to 1000 psi for 10 min. Drill out stage collar 00:00 01:00 1.00 0 0 INTRM2 WHDBO OTHR P Change heads in Iron roughneck to 4"-fill stack with water-work air out of system Page 54 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 07:30 6.50 0 0 INTRM2 WHDBO BOPE P Test BOPE as follows:annular to 250&2500 psi-Upper pipe rams, choke manifold valves,choke&kill line manual&HCR valves-Floor safety&dart valves-Auto&manual IBOP valves-Lower pipes to 250& 3500 psi-Performed accumulator recovery test-LD test jt.(5")-tested blind rams to 250&3500 psi- Tested upper and lower pipe rams and annular preventer with 3 1/2"and 4 1/2"test joints-Rams 250/3500- annular 250/2500 psi-Performed draw down test on super&manual chokes-Witnessing of test waived by Bob Noble w/AOGCC. Note: Electrician tested gas alarms. Blow down lines-RD test equipment 07:30 08:00 0.50 0 0 INTRM2 WHDBO OTHR P PJSM-Pull test joint and plug- install wear ring in wellhead 08:00 08:30 0.50 0 0 INTRM2 CEMEN-RURD P PJSM-Install abils and 4"elevators onto top drive 08:30 10:45 2.25 0 0 INTRM2 CEMEN-PULD P PJSM-PU and stand back 33 joints of 4"HWDP& 15 joints of 4"drill pipe 10:45 11:00 0.25 0 0 INTRM2 CEMEN-SFTY P PreJob safety meeting with crew on making up BHA 11:00 12:00 1.00 0 289 INTRM2 CEMEN-PULD P MU BHA#5-6 3/4"bit/BS/stab/ fs/(3)4 3/4"flex collars/xo/jars/ 5 jts.4"hwdp 12:00 20:45 8.75 289 8,205 INTRM2 CEMEN-TRIP P RIH w/clean out assembly- picking up 4"drill pipe from shed(252 jts)to 8205' 20:45 21:45 1.00 8,205 8,205 INTRM2 CEMEN-PRTS P PJSM-RU&Test casing above stage collar @ 8205'to 1000 psi for 10 mins.-Blow down lines-RD 21:45 22:30 0.75 8,205 8,327 INTRM2 CEMEN-WASH P Wash down f/8205 to 8327'(top of closing plug)@ 300 gpm @ 1650 psi w/60-80 rpm's @ 10-12 k torque 22:30 00:00 1.50 8,327 8,330 INTRM2 CEMEN-DRLG P Drilled closing plug&stage collar @ 8327'to 8330' - 7 bbls/min @ 1650 psi-WOB 8 to 18 k-70 rpm's @ 12 k torque-PU wt. 170 SO wt-110 Rot wt 130 04/08/2012 Wash to 8682'-Circ btms up-Re test csg to 1000 psi-S&C drill line&service TD-POOH-LD CO assembly-MU GeoPilot assembly-RIH picking up 4"DP f/shed to 8020' 00:00 01:15 1.25 8,330 8,682 INTRM2 CEMEN-REAM P Wash and ream from 8330'to 8682'- 300 gpm/1540 psi/80 rpm @ 12K torque-Rot wt. 140K 01:15 02:00 0.75 8,682 8,682 INTRM2 CEMEN-CIRC P CBU-300 gpm/1520 psi/80 rpm @ 12K torque 02:00 02:45 0.75 8,682 8,682 INTRM2 CEMEN-PRTS P PJSM-Flow check well-RU&Test casing below stage collar @ 8682'to 1000 psi for 10 mins.-Blow down lines-RD Page 55 of 72 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:45 04:30 1.75 8,682 8,682 INTRM2 RIGMNT SLPC P PJSM-Slip and cut 103'of drilling line-Service Top Drive-Adjust Drawworks brakes-Calibrate MD Toco block hieght 04:30 04:45 0.25 8,682 8,682 INTRM2 CEMEN-CIRC P Flow check well,static-Pump dry job-Blow down top drive 04:45 08:15 3.50 8,682 289 INTRM2 CEMEN-TRIP P POOH on elevators from 8682'to 289' 08:15 09:15 1.00 289 0 INTRM2 CEMEN-PULD P Flow check well,static-Stand back hwdp,&jars-LD bit, bit sub,&stab -stand back flex collars 09:15 09:30 0.25 0 0 INTRM2 CEMEN-SFTY P Held PJSM on picking up rotary Steerable BHA 09:30 10:45 1.25 0 102 INTRM2 CEMEN"PULD P MU BHA#7-GeoPilot 5200 Rotary Steerable Assembly 10:45 12:00 1.25 102 102 INTRM2 CEMEN-OTHR P Plug in and initialise MWD tools 12:00 13:00 1.00 102 393 INTRM2 CEMEN-CIRC P Finish MU BHA(PU NM flex DC's- jars-HWDP bumper sub)to 393'- Shallow pulse test MWD-250 gpm @ 980 psi 13:00 17:15 4.25 393 4,204 INTRM2 CEMEN-TRIPP Blow down TD-RIH f/393'to 4204' (picking up 4"DP f/pipe shed)- filling pipe every 20 stds 17:15 18:45 1.50 4,204 4,204 INTRM2 CEMEN"RGRP T Trouble shoot grabs/replace booster pump 18:45 19:15 0.50 4,204 4,204 INTRM2 CEMEN-CIRC P Circ&pulse test MWD w/ 250 gpm @ 1400 psi 60 rpm's @ 9 k torque 19:15 00:00 4.75 4,204 8,020 INTRM2 CEMEN"TRIP P Blow down TD-Cont. RIH f/4204'to 8020'(picking up 4"DP f/pipe shed) -filling pipe every 20 stds. PO wt. 148 SO wt 115 Rot wt 134 04/09/2012 RIH to w/GP assembly to 14,916'(tagged cmt)test casing to 3500 psi-Change well over to 9.8 ppg Flow Thru-Drilled shoe track+20'new hole-Perform FIT to 12.5 ppg-Drilled 6 3/4"hole to 15,310' 00:00 03:15 3.25 8,020 11,741 INTRM2 CEMEN-TRIP P RIH w/GeoPilot 5200 assembly from 8020'to 11741'-picking up 4"drill pipe from shed(total 357 jts.)-fill pipe every 20 stands 03:15 04:30 1.25 11,741 12,696 INTRM2 CEMEN-TRIPP RIH from 11,741'to 12,625' -SOW dropped 10K-Wash down from 12,625'to 12,696'-250 gpm/2810 psi-PUW 220K SOW 120K 04:30 05:15 0.75 12,696 12,982 INTRM2 CEMEN"TRIP P RIH from 12,696'to 12,816'-Lost 15K SOW-Wash and ream from 12,816'to 12,982'-250 gpm/2600 psi/30 rpm @ 16K ft/lbs torque- Rot.Wt. 155K 05:15 06:30 1.25 12,982 14,889 INTRM2 CEMEN"TRIP P RIH from 12,982',tagged TOC @ 14,916'(193'above baffle collar) PUW 250K SOW 120K Pulled up to 14,889' 06:30 06:45 0.25 14,889 14,889 INTRM2 CEMEN-CIRC P Circulated to clear contaminated mud from bit and BHA-250 gpm/ 2630 psi/30 rpm @ 18K ft/lbs torque Page 56 of 72 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:45 08:15 1.50 14,889 14,889 INTRM2 CEMEN"PRTS P PJSM-RU and perform casing pressure test to 3500 psi for 30 minutes-RD manifold and lines- blow down equipment 08:15 09:00 0.75 14,889 14,916 INTRM2 CEMEN-CIRCP Circulate and condition mud- prepare for FloThru displacement- 275 gpm/2690 psi/40 rpm @ 18K torque 09:00 10:30 1.50 14,916 14,916 INTRM2 CEMEN-CIRCP Displace well to 9.8 ppg FloThru mud system-Pumped 32 bbls of Safe Surf-O-spacer followed by 626 bbls of new mud system-Increased rpm to 100 as torque came down-PUW 245K SOW 115K Pumped at 275 gpm until new mud at bit-increased rate to 300 gpm-FCP=2920 psi 10:30 10:45 0.25 14,916 14,916 INTRM2 CEMEN-OTHR P Cleaned possum belly and pans under shakers 10:45 11:30 0.75 14,916 14,983 INTRM2 CEMEN"DRLG P Drill out cement from 14,916'to 14983'-300 gpm/2890 psi/80 rpm @ 14K torque-PUW 225K SOW 140K Rot.Wt. 175K 11:30 12:00 0.50 14,983 14,983 INTRM2 CEMEN"SFTY P Held safety meeting with both crews -Stood down Operations to share the limited information available regarding the fatal accident this morning on the North Slope-Advised the men to inform their supervisors if they felt distracted by grief of the loss-Suggested each contact their families and inform them the incident was not at Doyon 19 in the event there was misinformation being shared by news crews.Confirmed with all personnel that we could maintain our safety culture and focus if we returned to Operations. 12:00 20:15 8.25 14,983 15,278 INTRM2 CEMEN-DRLG P Drilled cement f/14,983'to 15104'- Drilled baffle collar @ 15,104'-cmrt to 15,148'-Drilled FC 2 15,148'- drilled cmt to 15,235'-Drilled FS @ 15,135'-Cleaned out rat hole to 15,258'-Drilled 20'new hole to 15,278' Note- All measurement are DP measurements-Top measurements from casing-Baffle-15,109' FC 15,154' FS 15,240' 20:15 21:30 1.25 15,278 15,278 INTRM2 CEMEN-CIRCP Circ btms up @ 300 gpm @ 2900 psi w/70 rpm's @ 14.5 k torque for FIT test-Blow down TD-Fow ck well static 21:30 22:30 1.00 15,278 15,278 INTRM2 CEMEN-FIT P PJSM-RU&perfrom FIT to 12.5 ppg EMW w/9.8 ppg mud w/960 psi applied pressure @ 6753'TVD- Bleed off pressure&RD-Blow down lines Page 57 of 72 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 15,278 15,310 PROD1 DRILL DDRL P ,Drilled 6 3/4"hole w/GP f/15,278'to 15,310'MD 6758'TVD ADT-1.25 hrs ECD-10.72 ppg Footage-32' WOB 5/12 k RPM 90 GPM 300 @ 2950 psi String wt- PU 225 SO 145 ROT 170 Torque on/off btm.-14/13 k ft/lbs X4/10/2012 Drill 6 3/4"hole f/15,310'to 15,843'-Touble w/ADR tool-Circ for trip-POOH for BHA to 9547' 00:00 01:15 1.25 15,310 15,399 PROD1 DRILL DDRL P Drilled 6 3/4"jhole w/GP f/15,310' to 15,399'MD 6769'TVD ADT-1.19 hrs ECD-10.91 ppg Footage-89' WOB 10/15 k RPM 120 GPM 300 @ 3140 psi String wt. PU 215 SO 145 ROT 175 Torque on/off btm.-14/12 k ft/lbs 01:15 01:45 0.50 15,399 15,399 PROD1 DRILL DDRL T Trouble shoot ADR tool-Pumping @ 300 gpm @ 2950 psi w/130 rpm's @ 13 k torque 01:45 09:00 7.25 15,399 15,843 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/15,399'to 15,843'MD 6766'TVD ADT-5.26 hrs. ECD-10.91 ppg Footage-444' WOB-10/15 k RPM 120 GPM 300 @ 3140 psi String wt- PU 215 SO 145 ROT 172 Torque on/off btm.-16/12.5 k fUlbs 09:00 09:30 0.50 15,843 15,843 PROD1 DRILL OTHR T Trouble shoot ADR tool-Attempt mode switch-No good 09:30 13:00 3.50 15,843 15,175 PROD1 DRILL CIRC T Circ 2 X btms-up @ 300 gpm @ 3120 psi w/120 rpm's @ 13 k torque -standing back 1 std DP every 30 mins f/15,843'to 15,175'-PU wt 215 SO wt 145 ROT wt 175 13:00 15:30 2.50 15,175 14,650 PROD1 DRILL TRIP T Flow ck well static-POOH on TT f/ 15,175'to 14,650'-improper hole fill 15:30 16:30 1.00 14,650 15,175 PROD1 DRILL TRIP T RIH f/14,650'to 15,175' 16:30 17:45 1.25 15,175 15,175 PROD1 DRILL CIRC T Circ btms-up @ 300 gpm @ 3100 psi -No influx @ btms up 17:45 21:00 3.25 15,175 12,314 PROD1 DRILL TRIP T Blow down TD-Flow ck well static- POOH on TT f/15,175'to 12,314'- hole taking proper fill 21:00 21:30 0.50 12,314 12,314 PROD1 DRILL CIRC T Flow ck well static-Pumped dry job @ 300 gpm @ 2600 psi-Blow down TD-Flow ck slight flow(f/dry job) 21:30 00:00 2.50 12,314 9,547 PROD1 DRILL TRIP T POOH on TT f/12,314'to 9,547'-PU wt. 165 SO wt 128-Hole taking proper fill 04/11/2012 POOH-Change out Geo-Pilot&ADR tool-RIH to 14,412'w/BHA#8-filling pipe every 20 stds 00:00 07:00 7.00 9,547 393 PROD1 DRILL TRIP T POH on trip tank from 9547'to 393'. Hole taking proper fill. Page 58 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:30 0.50 393 196 PROD1 DRILL TRIP T Flow check well. Static. LD jars. Std back HWDP. 07:30 07:45 0.25 196 91 PROD1 DRILL TRIP T Change elevators. Std back NMFDC's. 07:45 09:30 1.75 91 0 PROD1 DRILL PULD T Download MWD. LD BHA. 09:30 10:00 0.50 0 0 PROD1 DRILL OTHR T Clear floor. Prep for new BHA. 10:00 11:00 1.00 0 102 PROD1 DRILL PULD T PJSM.MU BHA#8. 11:00 12:00 1.00 102 102 PROD1 DRILL OTHR T Plug in&up load MWD tools 12:00 13:00 1.00 102 575 PROD1 DRILL PULD T PJSM-Finish MU BHA#8-MU float collar, NM flex DC's,jars, HWDP,Bumper sub, HWDP to 394'- Run 2 stds 4"DP to 575 13:00 00:00 11.00 575 14,412 PROD1 DRILL TRIP T RIH w/BHA#8 on 4"DP f/575'to 114,412'-Filling pipe every 20 stds. 04/12/2012 RIH to 15,175'-S&C drill line-RIH to 15748'-Wash&ream to 15,844'-Drilled 6 3/4"hole w/GP f/15844'to 16,988' 00:00 00:30 0.50 14,412 15,175 PROD1 DRILL TRIP T RIH w/BHA#8 on 4"DP f/14,412' to 15,175'-Filling pipe every 20 stds. Calc displacement-101.2 bbls. Actual displacement-99.5 bbls. 00:30 02:00 1.50 15,175 15,175 PROD1 DRILL CIRC T Flow check well-Static. CBU at 300 gpm-3160 psi-60 rpm. 02:00 03:45 1.75 15,175 15,175 PROD1 DRILL CIRC T Flow check well.Air breaking out at bell nipple.Slight flow down flowline. CBU at 300 gpm-3100 psi-80 rpm. 03:45 05:00 1.25 15,175 15,175 PROD1 DRILL SVRG P Flow check well-Static. PJSM.Slip and cut drilling line.Set block height. 05:00 05:30 0.50 15,175 15,748 PROD1 DRILL TRIP T RIH with 4"DP from 15,175'to 15,748'. Up wt-210k Dn wt-145k. 05:30 06:15 0.75 15,748 15,844 PROD1 DRILL WASH T Wash and ream from 15,748'to 15,844'. 06:15 12:00 5.75 15,844 16,167 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/15,844'to 16,167'MD 6760'TVD ADT-3.91 hrs. ECD-10.96 ppg Footage-323' WOB-10/15 k RPM 120 GPM 300 @ 3290 psi String wt- PU 210 SO 142 ROT 173 Torque on/off btm.-15.5/12 k ft/lbs 12:00 00:00 12.00 16,167 16,988 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/16,167'to 16,988'MD 6760'TVD ADT 9.18 hrs. ECD-11.7 ppg Footage-821' WOB 8/15 k RPM 120 GPM 300 @ 3290 psi String wt. PU 215 SO 140 ROT 175 Torque on/off btm.-14/12.5 k ft/lbs 04/13/2012 Drilled 6 3/4"hole w/GP f/16,988'to 18,309' Page 59 of 72 Time Logs Date From To Dur S.-'Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 16,988 17,753 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/16,988'to 17,753'MD 6734'TVD ADT 8.57 hrs. ECD-11.15 ppg Footage-765' WOB 8/15 k RPM 130 GPM 300 @ 3220 psi String wt. PU 215 SO 140 ROT 174 Torque on/off btm.-16/12.5 k ft/lbs 12:00 00:00 12.00 17,753 18,309 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/17,753'to 18,309'MD 6737'TVD ADT-9.22 hrs. ECD-11.11 ppg Footage-556' WOB-15 k RPM-130 GPM- 300 @ 3540 psi String wt. PU 215 SO 130 ROT 168 Torque on/off btm.- 15/14 k ft/lbs. "*Note went out of Nechelik sand up into Kup D shale @ 18,010' 04/14/2012 Drilled 6 3/4"hole w/GP f/18,309'to 18,627'-Circ btms up(no gas) Drilled 6 3/4"hole w/GP f/18,627'to 18,898'-Circ&wt. up to 10.1 ppg-Drilled 6 3/4"hole w/GP f/18,898'to 19,032' 00:00 11:00 11.00 18,309 18,627 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/18,309'to 18,627'MD 6749'TVD ADT 8.13 hrs. ECD-11.00 ppg Footage-318' WOB 10/13 k RPM 120 GPM 300 @ 3500 psi String wt. PU 223 SO 125 ROT 170 Torque on/off btm.-17.5/15 k ft/lbs 11:00 12:30 1.50 18,627 18,627 PROD1 DRILL CIRC P Circ btms up-check for inflex-300 gpm @ 3500 gpm @ 3500 psi w/120 rpm's 16 k torque-No gas @ btms up 12:30 17:00 4.50 18,627 18,898 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/18627'to 18,898'MD 6755'TVD ADT-2.60 hrs. ECD-11.05 ppg Footage-271' WOB 12/15 k RPM 120 GPM 300 @ 3470 psi String wt. PU 220 SO 132 ROT 172 Torque on/off btm.-18.5/11.5 k ft/lbs 17:00 20:45 3.75 18,898 18,898 PROD1 DRILL CIRC P Circ&wt. up f/9.8 ppg to 10.1 ppg- 300 gpm @ 3480 psi w/120 rpm's @ 15 k torque Obtain SPR's 20:45 21:00 0.25 18,898 18,898 PROD1 DRILL OWFF P Monitor well-static in 5 mins.-fluid level dropped 3"in 10 mins. Page 60 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 18,898 19,032 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/18,898'to 19,032'MD 6764'TVD ADT 2.44 hrs ECD-11.45 ppg Footage-134' WOB 8/15 k RPM 120 GPM 300 @ 3500 psi String wt. PU 220 SO 132 ROT 175 Torque on/off btm.-18.5/11.5 k ft/lbs. **Note hole started taking fluid eariler today-lost 60 bbls last 24 hrs. 04/15/2012 Drilled 6 3/4"hole to 19,375'(wt up to 10.3 ppg) Flow ck well slight flow-Cicr btms up Observed gas @ btms up-Circ&wt up to 10.5 ppg-Flow ck flow-Circ&wt up to 10.8 ppg-flow ck flow-circ&wt up to 11.1 ppg -Flow ck flow-Observed gas to surface after btms up from each flow ck&units of gas being reduced each time as wt.was increased-flow appeared to be slowing donw at each check but didn't go static 00:00 06:00 6.00 19,032 19,375 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/GP f/19,032'to 19,375'MD 6771'TVD ADT 4.45 hrs ECD-11.18 ppg Footage-343' WOB 13/15 k RPM 120 GPM 300 @ 3650 psi String wt. PU 230 SO 120 ROT 172 Torque on/off btm.-19.5/14.5 k ft/lb Start increasing mud wt to 10.3 ppg due to connection gas. 06:00 07:15 1.25 19,375 19,375 PROD1 DRILL CIRC P Finish circ and increase mud wt to 10.3 ppg.Shut down. Monitor well. Had decreasing flow for 10 min but did not stop. 07:15 09:00 1.75 19,375 19,375 PROD1 DRILL CIRC P CBU. Had gas and gas cut mud at bottoms up. 09:00 12:30 3.50 19,375 19,375 PROD1 DRILL CIRC P Circ and increase mud wt to 10.5 ppg.Shut down.Monitor well for 10 min. Had decreasing flow but did not stop after 10 min. 12:30 14:00 1.50 19,375 19,375 PROD1 DRILL CIRC P CBU. Had gas and gas cut mud at bottoms up. 14:00 17:00 3.00 19,375 19,375 PROD1 DRILL CIRC P Circ&wt. up f/10.5 ppg to 10.8 ppg @ 260 gpm @ 3100 psi- 17:00 19:30 2.50 19,375 19,375 PROD1 DRILL CIRC P Monitor well for 8 mins.-flowing - Circ btms up @ 225 gpm @ 2400 psi w/100 rpm's torque @ 18.5 K- 6000 stks)200 stks past calc btms up gas began to appear @ surface- 700 units @ driller's monitor(7.42% @ Co,.Man monitor)gas back down @ 6800 stks Page 61 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 19:45 0.25 19,375 19,375 PROD1 DRILL OWFF P Shut down pumps-Monitor well for 10 mins.-well flowing-rate appeared to be slowing down after 10 mins. Notified Drilling Engineer&Drilling Superentendent on plan forward 19:45 23:00 3.25 19,375 19,375 PROD1 DRILL CIRC P Circ&wt up f/10.8 ppg to 11.1 ppg @ 225 gpm @ 2400 psi w/100 rpm's ! 17.5 k torque Note-Btms up f/flow ckeck-gas peaked @ 500 units/6.4%w/10.8 ppg mud 23:00 23:30 0.50 19,375 19,375 PROD1 DRILL OWFF P Monitor well for 15 mins.- flowing- Rate appeared to be slowing down- obtain SPR's 23:30 00:00 0.50 19,375 19,375 PROD1 DRILL CIRC P Circ btms up @ 225 gpm @ 2400 psi w/100 rpm's @ 18 k torque Last 72 bbls mud to hole last 24 hrs -total losses 132 bbls 04/16/2012 Circ-Perform Exhale test(well dead)-Circ&bump wt to 11.3 ppg for trip-POOH f/19375'to 15,939' 00:00 02:15 2.25 19,375 19,375 PROD1 DRILL CIRC P Circ btms up after flow ck w/11.1 pp9- 02:15 03:15 1.00 19,375 19,375 PROD1 DRILL OWFF P Perform exhale test-Shut in well& monitored DP&casing pressure for 25 mins. 0 psi on Dp&Csg.- Opened well-well static 03:15 07:00 3.75 19,375 19,375 PROD1 DRILL CIRC P CBU at 225 gpm-2440 psi-50/90 RPMs-20k torque. No gas at bottoms up. 07:00 11:45 4.75 19,375 19,375 PROD1 DRILL CIRC P Circ and increase mud wt to 11.3 ppg at 190 gpm-2000 psi-90 rpms -19k torque. 11:45 12:00 0.25 19,375 19,375 PROD1 DRILL SFTY P Held a Hazard Awareness and Re-Focus Meeting on rig floor with both crews,service and support personnel. 12:00 13:30 1.50 19,375 19,375 PROD1 DRILL CIRC P Circ and increase mud wt in pits to 11.3 ppg at 190 gpm-2000 psi-90 rpms-19k torque. 13:30 13:45 0.25 19,375 19,375 PROD1 DRILL OWFF P Observed well.Slight flow down flowline. Static in less than 4 min. Obtain SPR's. 13:45 16:45 3.00 19,375 18,325 PROD1 CASING TRIP P POOH f/19,375'to 18,325'-pumping 4 bbls/min @ 1530 psi -PU wt.225 SO wt 120 FLow ck'ed each 5 stds.-slight flow slowing in 5 mins. Page 62 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 20:00 3.25 18,325 17,944 PROD1 CASING TRIP P BROOH f/18,325'to 17,944'@ 3 bbls/min @ 1080 psi w/100 rpm's @ 19 k toque-worked thru various tight spots. *Note:This is were the wellbore went out top&into Kup D shale& back into the Nechelik 20:00 00:00 4.00 17,944 15,939 PROD1 CASING TRIP P POOH w/pump @ 4 bbls/min @ 1340 psi-No rotation f/17944'to 15,939'-PU wt.245 SO wt 115 04/17/2012 POOH w/pump f/15,939'to 15175', monitor well-static,CBU, monitor, POOH w/pumps f/15175'to 11074', monitor, POOH on trip tank f/11074'to 3250',CBU, monitor, POOH on trip tank f/3250'to 394', monitor, Lay down BHA f/394'to 92',downlaod MWD. 00:00 01:45 1.75 15,939 15,175 PROD1 CASING TRIP P POOH w/pump @ 4.0 bbls/min @ 1340 psi-No rotation f/15,939'to 15,175'. Dropped rabbit on std #158. 01:45 02:00 0.25 15,175 15,175 PROD1 CASING OWFF P Monitor well. Static 02:00 04:00 2.00 15,175 15,175 PROD1 CASING CIRC P CBU at 4 bpm-1530 psi. 04:00 04:30 0.50 15,175 15,175 PROD1 CASING OWFF P Monitor well. Had small flow.Well static in 17 mins. 04:30 11:00 6.50 15,175 11,074 PROD1 CASING TRIP P POH w/pump from 15,175'to 11,074' at 4 bpm-1280 psi.Well was taking twice the required hole fill. 11:00 11:30 0.50 11,074 11,074 PROD1 CASING OWFF P Monitor well. Had small flow.Well static in 11 mins. Fluid level slowly dropping. 11:30 18:45 7.25 11,074 3,250 PROD1 CASING TRIP P POH on trip tank from 11,074'to 3250'. 18:45 19:15 0.50 3,250 3,250 PROD1 CASING CIRC P Circulate bottoms up to balance mud weight. Pumping 170 gpm w/710 psi. 19:15 19:30 0.25 3,250 3,250 PROD1 CASING OWFF P Flow check,static in 8 minutes. 19:30 19:45 0.25 3,250 3,250 PROD1 CASING OTHR P Blow down top drive. Fluid level dropped while blowing down the top drive. 19:45 21:30 1.75 3,250 394 PROD1 CASING TRIP P Continue to POOH on trip tank f/ 3250'to BHA @ 394' 21:30 21:45 0.25 394 394 PROD1 CASING OWFF P Monitor well at the HWDP.Slight drop in fluid. 21:45 23:30 1.75 394 92 PROD1 CASING PULD P Lay down BHA f/394'to 92'. Retieve rabbit on top of jars.Calc displacement 74.4 bbls,actual 93 bbls. 23:30 00:00 0.50 92 92 PROD1 CASING OTHR P Download Sperry Sun MWD. 04/18/2012 Finish downloading MWD, Lay down BHA, Rig up to run 4-1/2"liner, PJSM, Run liner, MU Baker liner hanger and ZXP packer, mix and install PAL mix in liner top, run a stand of 4",circulate 15 bbls, continue to RIH w/ liner on 4"dp f/4446'to 15242',circulate 11.3 ppg mud,stage rate up to 5 bpm w/1330 psi. 00:00 00:30 0.50 92 92 PROD1 CASING OTHR P Finish download Sperry Sun MWD. 00:30 02:15 1.75 92 0 PROD1 CASING PULD P POH LD BHA#8. 02:15 04:15 2.00 0 0 PROD1 CASING RURD P Clear rig floor. RU 4 1/2"liner equipment. Page 63 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 0 0 PROD1 CASING SFTY P PJSM on running liner. 04:30 10:45 6.25 0 4,327 COMPZ CASING RUNL P PU and RIH with 4 1/2"orange peel shoe on 4 1/2"12.6#L-80 liner. 73 jts IBTM-24 jts SLHT and 8 jts TSH-563. Ran 12 pert pups and 3 swell pkrs and 1 "XN"nipple. 10:45 11:15 0.50 4,327 4,373 COMPZ CASING RUNL P MU Baker SBE, liner hanger and ZXP liner top pkr. 11:15 12:00 0.75 4,373 4,373 COMPZ CASING OTHR P Mix and poor PAL Mix in top of pkr. Let set up. 12:00 12:30 0.50 4,373 4,446 COMPZ CASING RUNL P Change elevators to 4",then RIH w/ 4-1/2"liner f/4366'to 4446'on 4" S-135 XT39 drill pipe. 12:30 12:45 0.25 4,446 4,446 COMPZ CASING CIRC P Circulate 15 bbls @ 3 bpm w/200 psi. Blow down the top drive. 12:45 21:15 8.50 4,446 15,242 COMPZ CASING RUNL P Run in the hole w/4-1/2"liner on 4" drill pipe f/4446'to 15242'. Obtain PU&SO wt's every 10 stands, obtain rotating wt and torque every 30 stands. At 4463': PU wt 95k, SO wt 105k, Rot wt 102k w/20 rpm&4500 ftlbs of torque. At 15143': PU wt 124k,SO wt 225k, Rot wt 165k w/20 rpm&12k ftlbs of torque. 21:15 00:00 2.75 15,242 15,242 COMPZ CASING CIRC P Circulate,stage up f/1 bpm w/200 psi to 5 bpm w/1100-1330 psi.MW in 11.3 ppg, MW out was 10.3 ppg. Note: Mud losses for the day 78 bbls,total losses to the well=428 bbls. 04/19/2012 Circulate @ shoe-11.3 ppg mud, Monitor well-breathing to static, RIH w/4-1/2"liner f/15242'to 18105', Rotate liner through tight hole f/18105'to 18364', RIH w/liner f/18364'to 19358', Drop 29/32"ball, pump down to set liner hanger,set liner top packer,test, POOH to 14881', monitor well, pump spacer(HI-vis)pill, circ, monitor,displace to 11.3 ppg Sodium bromide brine,circ to balance, POOH f/14881'to 8690'@ midnight. 00:00 00:15 0.25 15,242 15,242 COMPZ CASING CIRC P Circulate 11.3 ppg mud,pumping 5 bpm w/1330 psi,then slow to 4.5 bpm w/1220 psi, last 30 bbls pumped @ 3 bpm w/640 psi. Pumped 610 bbls total. 00:15 00:45 0.50 15,242 15,242 COMPZ CASING OWFF P Monitor well-breathing,slowed down to static in 17 minutes. Bleed back 2 bbls. 00:45 04:30 3.75 15,242 18,105 COMPZ CASING RUNL P RIH w/4-1/2"liner on 4"S-135 dp f/ 15242'to 18105'. PU wt 240k,SO wt 120k. Note:Took 20k weight @ 18100'. 04:30 06:00 1.50 18,105 18,364 COMPZ CASING RUNL P Rotate liner through tight hole f/ 18105'to 18364'. Rotate 30 rpm w/ 16-17k ft lbs of torque. Rotating weight 167k. Slacking off 300-350' per hr(5-5.8'/minute) Page 64 of 72 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 07:45 1.75 18,364 19,358 COMPZ CASING RUNL P RIH w/liner on 4"dp f/18364'to 19347'.Make a top drive connection on a single. RIH f/19347'to 19358'. 07:45 09:15 1.50 19,358 19,358 COMPZ CASING CIRC P Drop 29/32"ball, pump ball down @ 3 bpm w/920 psi,slow down to 1.5 bpm w/475 psi prior to landing on seat.Set liner hanger by increasing pressure to 3000 psi,slack off to 80k to check that hanger is set.pressure to 3500 psi f/5 minutes to release liner, bleed to zero. Pick up free to 220k and clear dog sub,slack off and rotate down w/20 rpm&14.5k ft lbs of torque to set ZXP packer(set down to 82k on weight indicator). Good indication of packer setting. 09:15 09:45 0.50 19,358 19,358 COMPZ CASING DHEQ P Test ZXP packer to 1000 psi f/10 minutes(good). 09:45 10:15 0.50 14,992 14,881 COMPZ CASING TRIP P Lay down single,then rack back a stand of 4"drill pipe f/14992'to 14881'. 10:15 11:00 0.75 14,881 14,881 COMPZ CASING OWFF P Monitor well f/30 minutes-slight static loss. 11:00 13:45 2.75 14,881 14,881 COMPZ CASING CIRC P Circulate high vis pill surface to surface, pumping 5 bpm w/1460 psi. 13:45 14:00 0.25 14,881 14,881 COMPZ CASING OWFF P Monitor well f/30 minutes-breathing- static in 28 minutes. 14:00 14:15 0.25 14,881 14,881 COMPZ CASING SFTY P Pre job safety meeting on displacement f/11.3 ppg water based mud to 11.3 ppg Sodium bromide brine. 14:15 16:30 2.25 14,881 14,881 COMPZ CASING CIRC P Displace 11.3 ppg water based FloThru mud to 11.3 ppg NaBr Brine, pumping 5 bpm w/900 psi initial and 10 bpm w/3410 psi final. Depth 14881'. 16:30 17:30 1.00 14,881 14,881 COMPZ CASING OWFF P Clean under shakers. Monitor well- out of balance(dropping in annulus, flowing over drill pipe). 17:30 17:45 0.25 14,881 14,881 COMPZ CASING SFTY P Pre job safety meeting on circulating to even out(balance mud weight). 17:45 19:00 1.25 14,881 14,881 COMPZ CASING CIRC P Circulate bottom's up,pumping 6 bpm w/1230 psi. Reciprocate pipe slowly f/90'while circulating. 19:00 19:15 0.25 14,881 14,881 COMPZ CASING SFTY P Pre job safety meeting on tripping out of the hole w/Sodium bromide mud. 19:15 00:00 4.75 14,881 8,690 COMPZ CASING TRIP P Pull out of the hole f/14881'to 8690' using the trip tank. Hole taking a little over calculated fill. Note:Total losses sodium bromide f/the day 7 bbls,total loss of brine to the well 7 bbls. Note: Mud losses FloThru mud for the day 31 bbls,total losses of mud to the well=459 bbls. Page 65 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/20/2012 24 hr Summary POOH w/Baker liner running tool f/8690', L/D running tool, Pull wear bushing, RU/test BOPE-test witnessed by AOGCC insp Chuck Scheve, Slip&cut drill line, RU/Run 3-1/2"upper completion to 1658'. 00:00 05:15 5.25 8,690 52 COMPZ CASING TRIP P POOH using the trip tank-w/Baker liner running tool f/8690'. 05:15 05:45 0.50 52 0 COMPZ CASING PULD P Lay down Baker liner running tool. Good indication of packer set. 05:45 06:00 0.25 COMPZ WHDBO OWFF P Observe well-slight static loss. 06:00 06:30 0.50 COMPZ WHDBO OTHR P Pull FMC 8"ID wear bushing,set FMC upper test plug. 06:30 07:00 0.50 COMPZ WHDBO RURD P Rig up to keep hole full w/trip tank pump below test plug. 07:00 07:30 0.50 COMPZ WHDBO RURD P RU for BOPE test. Fill lines w/water. 07:30 07:45 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on testing BOPE. 07:45 12:00 4.25 COMPZ WHDBO BOPE P Test BOPE w/3-1/2"test joint. Witness of test by AOGCC insp Chuck Scheve. Held each test 5 minutes. Charted all tests. Tested annular to 250 psi low and 2500 psi high.Tested upper and lower pipe rams, choke valves 1-16, kill line and choke line valves and 4" demco valve on mud line to 250 psi low and 3500 psi high.Tested upper and lower IBOP on the top drive, tested FOSV and IBOP floor valve to 250 psi and 3500 psi.Tested accumulator.Tested gas alarms. Test w/4-1/2"test joint:Top and bottom pipe rams to 250 psi and 3500 psi. 12:00 12:30 0.50 COMPZ WHDBO RURD P Rig down testing equipment. Blow down choke manifold,choke and kill lines. Drain stack. 12:30 13:15 0.75 COMPZ WHDBO OTHR P Pull test plug. Install FMC wear ring for running the completion(9.125" ID). 13:15 13:30 0.25 COMPZ RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line. 13:30 14:15 0.75 COMPZ RIGMNT SLPC P Slip&cut 83'of 1-3/8"drill line. 14:15 14:30 0.25 COMPZ RIGMNT SVRG P Service top drive and drawworks. 14:30 17:45 3.25 COMPZ RPCOM RURD P RU to run 3-1/2"upper completion. Tongs,slips,spooling units, rig up sheaves for control line and encapsulated I wire, bring cannon clamps to the floor. Crossovers,floor safety valve crossover. Note: Sim ops-Replace 4"Demco bonnet assembly on#2 mud pump-mudline and test to 3500 psi-OK. 17:45 18:00 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on running 3-1/2"9.3 ppf L-80 EUE-m completion. Page 66 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 1,658 COMPZ RPCOM RCST P Run 3-1/2"9.3 ppf L-80 EUE-m completion: Baker 80-40 GBH locator seal assembly, 1 jt of 3-1/2" 9.3 ppf L-80 EUE-m tubing,3-1/2" pup jt,x-o,Schlumberger 3-1/2" NDPG single sub guage mandrel, x-o,3-1/2"pup jt,46 jts of 3-1/2" tubing, pup jt, HES 2.813""X"profile nipple w/RHC plug body installed, pup jt,2 jts of 3-1/2"tubing, pup jt, 3-1/2"Camco KBMG GLM w/DCK-2 SOV,pup jt,and one more jt of tubing to jt#50. Installed cannon clamps on every jt starting with the 2.19'pup above the guage mandrel. none on the pup below the X nipple, none on the"X" nipple,then one on the body of pup above the nipple and the box.The pup below the GLM has a 1/2 clamp on the body, none on the GLM,the pup above has a 1/2 clamp on the body and a clamp over the box. Check"I"wire when guage was hooked up,then every 30 jts-OK. Note:The pup below the x nipple w/RHC plug galled while making up (Pin end).Changed out jt#47 with jt 490 of tally,then corrected tally. Called for a new 10'3-1/2"EUE-m pup jt,drifted and measured,then made up on top of the nipple. Note:Total losses sodium bromide f/the day 32 bbls Note:Total losses of Fluid to the well=498 bbls 459 bbls mud and 39 bbls brine. 04/21/2012 Continue to run 3-1/2"upper completion f/1658'to 15023', Make up x-o, pump 1.5 bpm, slack off and locate w/seals on seal assembly,shut down pumps, open bleeder,slack off to locate, mark pipe, POOH to 15022', circulate 11.3 ppg sodium bromide brine. 00:00 12:00 12.00 1,658 9,119 COMPZ RPCOM RCST P Run 3-1/2"9.3 ppf L-80 EUE-m completion: Continue f/jt#51 to #110,then pup jt, GLM w/dummy, pup jt,continue w/jts #111-#289 to 9119' Installing cannon clamps on every jt. The pup below the GLM's has a 1/2 clamp on the body, none on the GLM,the pup above has a 1/2 clamp on the body and a clamp over the box. Check"I"wire every 30 jts-OK. Page 67 of 72 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 21:45 9.75 9,119 15,023 COMPZ RPCOM RCST P Run 3-1/2"9.3 ppf L-80 EUE-m completion: Continue Run a pup jt, GLM w/dummy, pup jt, continue jt# 290 to#402,then a pup,TRMAXX-5E SSSV,pup,then jt#403 to#479. Installing cannon clamps on every jt. The pup below the GLM's has a 1/2 clamp on the body, none on the GLM,the pup above has a 1/2 clamp on the body and a clamp over the box. The pup below the SSSV has a 1/2 clamp on the body, none on the SSSV,the pup above has a 1/2 clamp on the body and a clamp over the box. Check"I"wire every 30 jts-OK. PU wt 148k, SO wt 102k. Calculated displacement 51.1 bbls, actual was a loss of 14 bbls. 21:45 22:00 0.25 15,023 15,023 COMPZ RPCOM SFTY P Pre job safety meeting. 22:00 22:15 0.25 15,023 15,023 COMPZ RPCOM RCST P Make up a crossover(4"XT39 box x3-1/2"EUE pin)to joint#480, make up joint#480. Make a top drive connection. 22:15 22:30 0.25 15,023 15,022 COMPZ RPCOM RCST P Circulate, pumping 1.5 bpm w/100 psi. Slack off to locate w/seals of seal assembly. Pressured up to 150 psi when seals entered the Seal Bore extension(15028.41'by tubing tally). Shut down pump.Slack off the locate. Locate w/mule shoe @ 15047.41'tubing tally measurement. Pick back up above the seal bore extension to 15022'. PU wt w/seals in SBE 155k,SO wt w/seals in the SBE 100k. 22:30 22:45 0.25 15,022 15,022 COMPZ RPCOM SFTY P Pre job safety meeting on circulating. 22:45 00:00 1.25 15,022 15,022 COMPZ RPCOM CIRC P Pump 300 bbls of clean 11.3 ppg brine @ 5 bpm w/1050 psi. Note:Total losses sodium bromide f/the day 28 bbls Note:Total losses of Fluid to the well=526 bbls 459 bbls mud and 67 bbls brine. 04/22/2012 Spot 78.5 bbls corr inhibited 11.3 ppg sodium bromide brine w/mule shoe @ 15022',Space out, pull wear bushing, MU FMC hanger,terminate and test lines to hanger, RIH land tubing, RILDS,test ann,test hanger seals, monitor well,test tbg,test annulus,shear SOV, install TWC, attempt to test TWC,test hanger seals, test TWC, monitor well, clean stack, blow down lines, ND BOPE,teminate lines through wellhead,test control line&"I"wire, NU tree,test hanger neck seals,test tree, pull TWC, RU f/freeze protect, PJSM. 00:00 01:00 1.00 15,022 15,022 COMPZ RPCOM CIRC P Pump 78.5 bbls inhibited 11.3 ppg sodium bromide brine from vac truck, follow with 129.5 bbls of 11.3 ppg sodium bromide,w/mule shoe @ 15022'. Pumping 5 bpm w/1040 psi. Page 68 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:45 1.75 15,022 15,010 COMPZ RPCOM HOSO P Lay down 7 joints of 3-1/2"9.3 ppf L-80 EUE-m tubing to jt#473 in the hole. Pick up 2 joints of 3-1/2"tubing for a total of 475 joints of 3-1/2"in the hole. Make up 4-1/2"IBT-m box x 3-1/2"EUE pin crossover,then(3) 4-1/2"12.6 ppf L-80 IBT-m space out pups(9.84',9.82'and 7.82'),follow w/ (2)joints of 4-1/2"IBT-m joints of tubing. Mule shoe depth 15010.78'. PU wt 148k, SO wt 105k. Installing 3-1/2"cannon clamps on every jt up to jt#474.The first pup above the crossover has a 4-1/2" clamp over the box, none on the next 2 pups,then a 4-1/2"clamp over the box of the first 4-1/2"joint and a clamp on the body of the second 4-1/2"joint.. Check"I"wire -OK. 02:45 03:30 0.75 15,010 15,010 COMPZ RPCOM OTHR P Make up FMC wear ring pulling tool. Slack of and retrieve the wear ring. Pick up and bring wear bushing to the floor. Turn off trip tank pump to monitor well visually. Hole taking a little fluid. 03:30 03:45 0.25 15,010 15,010 COMPZ RPCOM RCST P Make up FMC metal to metal 4-1/2" tubing hanger(5"4SAM2-2G RH Acme thread top,and landing joint. 03:45 04:00 0.25 15,010 15,010 COMPZ RPCOM OTHR P Terminate the 1/4"control line f/the SSSV and the"I"wire.Test connections at the hanger to 5000 psi f/5 minutes-OK. 04:00 04:30 0.50 15,010 15,010 COMPZ RPCOM PRTS P Test connection to the hanger for the "I"wire to 5000 psi f/5 minutes-OK. 04:30 04:45 0.25 15,010 15,010 COMPZ RPCOM PRTS P Test connection to the hanger for the SSSV to 5000 psi f/5 minutes-OK. Wrap both the"I"wire and the control line around the neck of the hanger. Secure to the hanger neck. 04:45 05:00 0.25 15,010 15,046 COMPZ RPCOM RCST P Run in the hole and land the tubing in the FMC well head.When landed, the mule shoe of the seal assembly @ 15046.12',spaced out 1.29'from fully located. PU wt 148k, SO wt 105k, Block weight 72k. 05:00 05:30 0.50 15,046 15,046 COMPZ RPCOM OTHR P Run in lock down screws.Torque to 450 ft lbs. 05:30 06:00 0.50 15,046 15,046 COMPZ RPCOM DHEQ P Rig up,then test the annulus to 1000 psi f/10 minutes to verify seals in the SBE. Chart test. 06:00 06:45 0.75 15,046 15,046 COMPZ RPCOM DHEQ P Remove landing joint,install two way check, install landing joint.Test hanger seals to 5000 psi. Pull the two way check. 06:45 07:15 0.50 15,046 15,046 COMPZ RPCOM OWFF P Monitor well.Static losses. Rig down equipment from rig floor. Page69of72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:45 1.50 15,046 15,046 COMPZ RPCOM RURD P Continue to clear floor of tools. Rig up squeeze manifold and 2" hardlines from cellar to rig floor. 08:45 09:15 0.50 15,046 15,046 COMPZ RPCOM RURD P Fill lines,then pressure test lines to 4000 psi. 09:15 10:30 1.25 15,046 15,046 COMPZ RPCOM DHEQ P Test tubing to 4000 psi for 30 minutes. Bleed tubing down to 2000 psi.Test tubing x 7-5/8"annulus to 3500 psi f/30 minutes. Bleed tubing down to shear DCK-2 SOV in GLM @ 13429'.All tests charted. 10:30 11:00 0.50 15,046 15,046 COMPZ WHDBO RURD P Pull landing joint. Install two way check, install landing joint. 11:00 12:00 1.00 15,046 15,046 COMPZ WHDBO DHEQ P Pressure test two way check by pumping down the 7-5/8"x3-1/2" annulus.Attempt test(failed), pull two way check, rebuilt and re installed two way check. 12:00 12:15 0.25 15,046 15,046 COMPZ WHDBO SFTY P Pre job safety meeting/crew change. 12:15 12:30 0.25 15,046 15,046 COMPZ WHDBO DHEQ P Test FMC hanger seals to 250 psi f/ 5 minutes,test to 5000 psi f/10 minutes-good. 12:30 13:00 0.50 15,046 15,046 COMPZ WHDBO DHEQ P Pressure test the two way check by pumping down the 7-5/8"x 3-1/2" annulus against ball&rod landed in the RHC plug body @ 13519'and the DCK-2 Sshear out valve(sheared)in the GLM @ 13429'.Test two way check to 2500 psi f/5 minutes-good. 13:00 13:30 0.50 15,046 15,046 COMPZ WHDBO OWFF P Monitor annulus f/30 minutes-no flow. 13:30 13:45 0.25 15,046 15,046 COMPZ WHDBO SFTY P Pre job safety meeting. 13:45 14:15 0.50 15,046 COMPZ WHDBO RURD P Rig down 2"hardlines and hoses. Lay down landing joint. 14:15 14:30 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on cleaning stack insides. 14:30 15:00 0.50 COMPZ WHDBO RURD P Rig up stack wasing tool,then wash stack. 15:00 16:00 1.00 COMPZ WHDBO OTHR P Blow down the top drive, mud lines, choke and kill lines, and hole fill. Drain stack using a super sucker to clean out stack. 16:00 16:15 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 16:15 17:15 1.00 COMPZ WHDBO NUND P Nipple down 13-5/8"BOPE. 17:15 19:00 1.75 COMPZ WHDBO RURD P FMC rep Guy and Schlumberger rep Billy working to terminate the control line and"I"wire through FMC well head. 19:00 19:15 0.25 COMPZ WHDBO DHEQ P Test the control line to 5000 psi f/10 minutes-good. Final reading on"I wire: BHP 3598 psi,temp 160.01 psi. 19:15 19:30 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on nippling up FMC tree. Page 70 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 COMPZ WHDBO NUND P Nipple up FMC tree. 20:30 20:45 0.25 COMPZ WHDBO PRTS P Test hanger neck seals and api ring gasket/flange to 5000 psi f/10 minutes-OK. 20:45 21:00 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on rigging up and testing tree. 21:00 21:15 0.25 COMPZ WHDBO DHEQ P Rig up to test tree. 21:15 22:00 0.75 COMPZ WHDBO DHEQ P Test tree to 250 psi low and 5000 psi high. Chart test. 22:00 22:30 0.50 COMPZ WHDBO RURD P Rig up lubricator,then pull two way check. 22:30 23:15 0.75 COMPZ WHDBO RURD P Rig up hardlines and hose for freeze protecting tubing and annulus. 23:15 23:30 0.25 COMPZ WHDBO PRTS P Test hardlines and hoses to 3140 psi w/rig pumps. 23:30 00:00 0.50 COMPZ WHDBO SFTY P Pre job safety meeting on freeze protecting well w/diesel.Will pump 201 bbls into well, pumping down the tubing,taking returns f/annulus. Tubing cap 117.5 bbls,will have 83.5 bbls in the annulus. Note:Total losses sodium bromide f/the day 12 bbls Note:Total losses of Fluid to the well=538 bbls 459 bbls mud and 79 bbls brine. 04/23/2012 Dowell pump freeze protect diesel(201 bbls into well-117.5 in tubing,83.5 in annulus). Set BPV,secure well. Lay down 4"dp f/derrick. PJSM on moving MI Swaco ball mill.Jack up ball mill. Jack up pipe shed. Cleaning drip pans and cellar area, prep to move to CD3-127(160'move). Rig released @ 2359 hrs 4/23/2012. 00:00 02:00 2.00 COMPZ WHDBO FRZP P Dowell pump 3 bbls diesel,test lines to 4500 psi. Bleed off pressure,then pump down the tubing @ 2.1 bpm w/ initial 1722 psi taking returns up the 7-5/8"x 3-1/2"annulus. Final pressure was kept @ 2900 psi w/ 600 psi on the annulus. Pumped a total of 201 bbls into the well. Shut in well.Tubing cap 117.5 bbls,will have 83.5 bbls of diesel in the annulus (2455'MD). 02:00 02:45 0.75 COMPZ WHDBO RURD P Flush lines w/water, blow down lines. Rig down squeeze manifold and 2"hardline and hoses. 02:45 03:00 0.25 COMPZ WHDBO SEQP P Make up FMC lubricator. 03:00 03:15 0.25 COMPZ WHDBO SEQP P Test lubricator with test pump to 3600 psi.Observed pressure guage-OK. 03:15 03:30 0.25 COMPZ WHDBO SEQP P Set Type"H"BPV using lubricator. Rig down lubricator. Pressure on tubing was 1250 psi prior to setting BPV. 03:30 03:45 0.25 COMPZ WHDBO SEQP P Suck out diesel from the tree with super sucker. Install tree cap w/ guage.Shut master and swab valve. Page 71 of 72 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 04:45 1.00 COMPZ WHDBO NUND P Secure Well: Remove double valve on upper annulus, install companion flange w/needle valve and gauge. Reading on upper annulus was zero. Install gauge on lower annulus, reading was 400 psi. 04:45 05:15 0.50 COMPZ RIGMNTSVRG P Service rig. 05:15 05:30 0.25 COMPZ DRILL SFTY P Pre job safety meeting on laying down 4"drill pipe f/the derrick. 05:30 16:45 11.25 COMPZ DRILL PULD P Lay down 4"drill pipe from the derrick. 16:45 17:15 0.50 COMPZ RIGMNT SVRG P Service rig. 17:15 17:30 0.25 COMPZ DRILL SFTY P Pre job safety meeting. 17:30 23:00 5.50 COMPZ DRILL PULD P Continue to lay down 4"drill pipe from the derrick. Layed down a total of 171 stands of 4"dp,5 stands of 4" HWDP. Left 37 stands of 4"dp in the derrick and 6 stands of 4"HWDP in the derrick. 23:00 23:45 0.75 COMPZ DRILL OTHR P Clean rig floor drip pans. Prepare cellar, prep to move f/CD3-119 to CD3-127. Sim Ops: PJSM on moving MI Swaco Ball Mill,Jack up ball mill. Jack up pipe shed. Note:Total losses of Fluid to the well=538 bbls 459 bbls mud and _79 bbls brine. 23:45 00:00 0.25 COMPZ DRILL SFTY P Pre job safety meeting. Page 72 of 721 HALLIBURTON Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska April 24, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-119 AK-MW-0008520721 CD3-119 50-103-20653-00 2" x 5" MD GAMMA RAY/RESISTIVITY Logs: 1 Color Log fr 2" x 5"TVD GAMMA RAY/RESISTIVITY Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Rom # 2. i(--tc(6 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@halliburton.com .) Date: )c- r ztV Signed: 2NI Page 1 of 2 • r Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 20, 2012 8:55 AM To: 'Samuell, JG (John G)' Cc: Herbert, Frederick 0 Subject: RE: CD3-119 Intermediate Plug Back ft's /Z- - c JG, The log shows marginal Qannik reservoir but still needs to be isolated. Your proposal fulfills regulatory requirements as set forth by 25AAC 25.112 (a)(1). Tagging the Qannik plug will not be required as you are setting a ECP for a base to lay cement on. Good luck on your next attempt on drilling the intermediate hole. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Samuell,JG (John G) [mailto:John.G.Samuell@conocophillips.com] Sent: Monday, March 19, 2012 9:11 PM To: Schwartz, Guy L(DOA) Cc: Herbert, Frederick 0 Subject: CD3-119 Intermediate Plug Back Guy, As per our conversation,we are planning to plug back the 9-7/8"intermediate hole section on CD3-119 to the surface casing shoe. I have attached a schematic that details the cement that is already in place, as well as the two plugs we will need to set to isolate the Qannik and the other to provide a kick off point. I have also attached the log that details the location of the Qannik and the hydrocarbon bearing zone that ranges from 8064'MD to 8111'MD. We will set an open hole, inflatable packer as the base for the Qannik plug. J.G. Samuell Dr Engineer:Co ocoPnilips Alaska Direst Mohile ,832 3...48 3/20/2012 Page 2 of 2 CD3-119PB1 RKB - GL = 36.3' Updated 03/19/12 Wellhead 16" Conductor to 114' 10.5 PP9 mud in hole { 10-3/4"45.5 ppf L-80 BTCMi _ Top of Plug (200' in casing) Surface Casing ~` N 3,450'MD 'MDI 2483TVD' • €: @ 3650 :.;,,,.::€€ Btm of Plug (300' below casing) 11 cemented to surface ' '11 � LE 3.950' MD 30 bbls hi vis Top Qannik .....:,:.•:.:::::::: ::: :::� Top of Plug (200'Above Pay) 8,064'MD!4132'TVD ••�� 7864'MD 11111111§110.101111111 1111111) 11111111 Btm of Plug (200' Below Pay) Base Qannik 115111111111MiiiiiniN 8311' MD 8335'MD I 4235' TVD ECP Set at 8311' MD Current 12367 Plug#2: 500' Kick off plug Top at KOP +1- '"'' J ' € 500 +1-12367 MD 1/_ppa, 12,667' 12867 Hi Vis U Spacer/ 1946 Drilling 1 14813 Mud :i'l>l_':il"'s':' ii 800 Plug#1 : +i-800'Top +/-14813'MD T�Nechetik Reservoir at ` ' ' " ' :::��:�:::::::::::::>:: 15.8 ppq +/-15208'/6729'MD Pilot Hole a +1- 68 deg TD at +1- 15613' MD /6870 TVD 3/20/2012 7650 III ..' 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' ,;' 1 Schlumberger Drilling&Measurements ConocoPhillips 2525 Gambell Street.Suite 400 Anchorage AK 99503 Tel(907)273-1700 Fax(907)561-8317 Date: 03-Apr-2012 Well Name: CD3-119 Company: ConocoPhillips E&P Alaska API Number: 50-103-20653-00-00 AFE Number: 10329832 Field: Colville River Rig: Doyon 19 • b2 ,2° 7 ti Schlumberger ConocoPhillips Alaska Formation Evaluation 9-7/8 inch Sidetrack Section: The Sidetrack section was drilled from 3,589 to 15,258.00 feet in three runs with a BHA composed of PowerDrive* Xceed, arcVISION* and TeleScope* (with an Multi-Vibrational-Chassis cartridge and IWOB). Gamma Ray, Resistivity and ECD were measured by the arcVISION*tool and were supplied in both Real-Time and Recorded Mode. Real-time multi-vibrational measurements were obtained from the MVC of the TeleScope* MWD tool, which provided the information necessary to help mitigate shocks and vibration, and the IWOB was used for drilling parameters optimization. In the first run an attempt to sidetrack from 12,475 ft MD was made,however it was not possible to drill due to the high torque.Therefore decision was made to pump a cement plug and sidetrack from the casing shoe. No formation was drilled during run 2 as no cement was found at the expected depth, BHA was POOH and a new cement plug was pumped.Sidetrack form 3,589 ft MD to TD was successfully drilled in run 3. Innovation The Schlumberger MWD team was successfully able to demodulate real-time data at a bit rate of 6 bits per second during all sections of the well, up to and including the point of TD 15,258.00,with most Xceed downlinking occurring on bottom while drilling. We would like further encourage the use of MVC (Modular Vibration Chassis) and IWOB to improve drilling performance and tool reliability, as well as ECD measurements to enable informed decisions about drilling practices. Schlumberger Oilfield Services— Drilling & Measurements appreciates the opportunity to provide ConocoPhillips E&P Alaska with MWD and LWD services. Sincerely, Luke Edwards MWD/LWD Engineer Schlumberger Drilling&Measurements Schlumberger �� Drilling&Measurements Con hh5 2525 Gambell Street.Suite 400 Alaska Anchorage AK 99503 Tel(907)273-1700 Fax(907)561-8317 Date: 14-Mar-2012 Well Name: CD3-119PB1 Company: ConocoPhillips E&P Alaska API Number: 50-103-20653-00-70 AFE Number: 10329832 Field: Colville River Rig: Doyon 19 Schlumberger ConocoPhillips Alaska Formation Evaluation 13-1/2 inch Surface Section: The surface hole section was drilled out of the 16"conductor from 114 feet to a measured depth of 3,661 feet in one single run. TeleScope* was picked up along with PowerPak* motor, no high periods (> 1 hr) of Stick&Slip were encountered during this run. All survey corrections were made and implemented by Sperry Survey Center. Survey were corrected during run with pre-sag modeling,post-sag correction was run after the run. 9-7/8 inch Pilot hole Section: The Pilot hole section was drilled from 3,661 to 15,613.31 feet in one run with a BHA composed of PowerDrive*Xceed, EcoScope*, TeleScope* (with an Multi-Vibrational-Chassis cartridge and IWOB) and Sonic VISION. Gamma Ray, Resistivity, Density, Neutron Porosity, and ECD were measured by the EcoScope* and were supplied in both Real- Time and Recorded Mode. Advanced EcoScope* measurements such as Spectroscopy were provided in Recorded Mode. Also Compressional DT, measured by the SonicVISION*,was supplied in both Real-Time and Recorded Mode. Real-time multi-vibrational measurements were obtained from the MVC of the TeleScope* MWD tool, which provided the information necessary to help mitigate shocks and vibration, and the IWOB was used for drilling parameters optimization. Innovation The Schlumberger MWD team was successfully able to demodulate real-time data at a physical bit rate of 6 bits per second during all sections of the well, up to and including the point of TD 15,613, with most Xceed and SonicVISION downlinking occurring on bottom while drilling. We would like further encourage the use of MVC (Modular Vibration Chassis) and IWOB to improve drilling performance and tool reliability, as well as ECD measurements to enable informed decisions about drilling practices. With the use of Orion Dpoints it was possible to provide high quality real time data for gamma ray, resistivity,density and neutron porosity in a complicated BHA using physical bit rate of only 6 bits per second. Schlumberger Oilfield Services— Drilling & Measurements appreciates the opportunity to provide ConocoPhillips E&P Alaska with MWD and LWD services. Sincerely, Stephen Fell MWD/LWD Engineer Schlumberger Drilling&Measurements _ r NNN [-sai Al. s /A SEAN PARNELL, GOVERNOR d ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-119 ConocoPhillips Alaska, Inc. Permit No: 212-007 Surface Location: 3984' FNL, 1030' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 3587' FNL, 2545' FEL, SEC. 20, T13N, 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, 4.6 Daniel T. Seamount, Jr. Chair DATED this Z 3 day of January, 2012. cc: Department of Fish 8s Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA • AL A OIL AND GAS CONSERVATION COMh, ON ��* PERMIT TO DRILL 20 AAC 25.005 j',' 1, 7 2012 la.Type of Work: lb.Proposed Well Class: Development-Oil El- Service- Winj E Single Zone ❑ - lc.Specify if well is proposed for ; Drill ❑., - Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ 3oalbed•Gas-'[ '-t it5H $ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ t c 1 flit Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD3-119 ' t Pd.-F kJ-4-- 3.Address: 6. Proposed Depth: 12.Field/Pool(s): P.O.Box 100369 Anchorage,AK 99510-0360 MD: 21178.2 " TVD: 6899.1 Colville River Field 4a. Location of Well(Govemmental Section): 7.Property Designation(Lease Number): Surface: 3984'FNL, 1030'FEL,Sec05,T12N,R5E 372105,372104,364470,364471,364472 Fiord Oil Pool Top of Productive Horizon: 8.Land Use Permit:LAS 2112 13.Approximate Spud Date: 2910'FNL,4485'FEL,Sec28,T13N,R5E Tobin 931986,931974,931976,932002,932000 15-Feb-12 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3587'FNL,2545'FEL,Sec20,T13N,R5E 15916 1.5 mi from ADL 391161 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 49.1 feet 15.Distance to Nearest Well Open Surface: x-388012.95'• y- 6003792.97' • Zone-4 GL Elevation above MSL: • 12.8 feet to Same Pool: CD3-107L1, 842' 16.Deviated wells: Kickoff depth: 230 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89 degrees Downhole: 3076 . Surface: 2396 - 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" _ 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-Installed i4- 1•/'1.12, 13.5" 10.75" 45.4# L-80 BTC-M 3681 37' 37' 3718' 2500' 1058 Sx ASL&270 Sx Class G 9.875" 7.625" 29.7# L-80 BTC-M 13439 37' 37' 13476' 6162' 37S 10.75" 7.625" 29.7# L-80 BTC-M 2006 13476' 6162' 15482' 6819 1st:.26T Sx Cls.G/2st:272 Cls.G 6.75" 3.5" 12.6# L-80 EUE-8rd-M 15240' 32' 32' 15272' 161/3/04 6.75" 4.5" 12.6# L-80 TSH-563 5888' 15272' 21160' 6879' sliding sleeve,swell packer,uncmt. L.,19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): None Perforation Depth TVD(ft): None 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑., 20 AAC 25.050 requirements❑., 21. Verbal Approval: Commission Representative: Date 17-Jan-12 22. I hereby certify that the foregoing is true and correct. Contact J.G. Samuel!@ 907-265-6309 10' Printed Name /// C.Alvord Title Alaska Drilling Manager Signature �l .( & Phone 265-6120 Date /11-1(2''' I L_ / Commission Use Only Permit to Drill LAS''-.7 API Number: �`.n -, Permit Appr va \ezio See cover letter for other Number: Z�� / 50-<`.. � 2� �(- Date: k �� \ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: „x 39,0 ,OSC, sop 1CS f Samples req'd: Yes ❑ NoR^"/ Mud log req'd: Yes ❑ o H2S measures: Yes❑ No LJ/ Directional svy req'd: Yes R No ❑ p,,,e_ert-- I,tJazuc...Q pAA. 2...- bac-. -2_. --0 ? c(4) (L) Lib I / Z 3 ( ZDATE: ir, / APPROVED BY THE COMMISSIONER 6/04•••) -Iq_1 .�z Form 10-401(Revised 7/2009) This permit is valid for 24 nlohtis^fron5 the'da'tetof approval(20 AAC 25.005(g)) Submit in li! ConocoPhillips Alaska, Inc. Post Office Box 100360 `'"- Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 fl January 17th, 2012 Alaska Oil and Gas Conservation Commission i L+ 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Alaska Oil R Gas<,ons. Commission Re: Application for Permit to Drill CD3-119 Anchorage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore horizontal production well from CD3 drilling pad. It is intended for Doyon Rid 19 to be used to drill this well with a spud date of 02/15/2012. CD3-119 is planned to be a horizontal Nechelik sand producer.A pilot hole, CD3-119PB1,will be drilled to the Nechelik at 66°. The pilot hole will be abandoned with 2 cement plugs.Then the well, CD3-119,will be kicked off at approximately 14,127'MD and landed in the Nechelik sand horizontally. It is expected that the K2(Qannik)and Kuparuk sands will be considered hydrocarbon bearing zones. Both formations will be cemented through a two-stage cement job to a minimum 500'above the top of each reservoir after setting the 7-5/8"casing. After setting and cementing the 7-5/8" intermediate casing,the 6-3/4"horizontal section will be drilled and the well completed as a producer with ball actuated frac sleeves and swell packers. It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2) is granted. At CD3,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 with request for approval of annular pumping operations 3. A proposed completion diagram 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/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 J.G. Samuell at 265-6309 (John.G.Samuell@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, J.G. Samuel) Drilling Engineer /.// r cc: CD3-119 Well File/Sharon Allsup-Drake ATO 1530 Liz Galiunas ATO 1500 Chip Alvord ATO 1570 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation Apr 'on for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 Attachment 3-Well Schematic Colville River Field CD3-119 WP12 Nechelik Production Well 16"Conductor to 114' Upper Completion MD TVD J lilliil ` 1)Tubing Hanger 2)4=4"12.6#/ft IBT-M Tubing(2 jts), 4-172" 12.6# 1.80 IBT-M 3) X0 4-h"12.6#IBT-M x 3-W 9.3#EUE-&d-M L-80 � ',kiting binr o 130 MD L J 4)Cameo 3.5'TRMAX)t-SE SSSV wf 2.812"X profile(66.6°) 2439' 2000' with control line to surface. Y Cannon Cross-couping clamps on every joint iiiiiii ). Frac sleeve to be run off-rig will have a 2.31"ID iiiiiii 0 -5)3-W x 1"Cameo KBMG GLM wf DV 68° 6121' 3400' 6)3-h"x 1"Cameo KBMG GLM wf DV 68" 11994' 5600' 10-314"45.5#L-80 BTC-M 7)3-'W X 1"Cameo KBMG GLM wJDCK2 69" 14600 6589' .4 Ilk Surface Casing Pinned for 2500 psi casing to tbg shear "3718'MD 12500 TVD 8)HES 2.813'X-Profile w!RHC plug body 70,5' 14690 6636' k oc cemented to surface 9)S1.8 Bottom Hole Pressure Gauge 15212' 6776' Encapsulated 1-Wire w1 Cannon clamps on every jjant. Calculated TCC a 10)BOT 80-40 GBH Locator 80" 15272' 6787' 7' 500'MD above top of 0enn9t • Lower Completion • 1 11)Baker 5.5 X 7-578"HRD ZXP Liner top Packer(80') 15301' 6793' Top Clannik Baker 5.5"RS Nipple TSH-563 8x8 8094'MDT 41139'TVD 168° l Baker 5.5"x 7-5+8"Flex Lock Liner Hanger TSH"563 0.1') 15323' 6796 d` XO 5.5'Hydril 563 Box x 5"TSH-563 Box (8 HES 7"Stage Collar Baker 80-40 20'x 4".10 Seal Bore Extension Hydril 563 PxP 15334' 6798' 500 MD below bottom of XO 5"Hydra 563 Box a 4.1,2"TSH-563 pin Cannik 1214.W.12.6 31ft.TSH-563 Tubing 9) HES 2.813'XN with 2.75"NoGo(81.7") 15394' 6807' 13)Freecap I FSC-11 6.38"ODSwell Packer re 6.5"OD Cementralizer -15400'MD 14)Freecap I FSC-11 6.38"CCSwet i Packer w16.5"OD Carnentrallzer -15500'MD 15)Baker Fracpoint EX-C Ball Actuated Sleeve(2.073"Seat for 2.125"Ball) 0 c 16)Freecap I FSC-11 6.36"00Swell Packer wf 6.5"OD Cementralizer ._.-�-. 17)Baker Fracpoint EX-C Ball Actuated Sleeve(2.011"Seat for 2.063"Ball) 3 Wellbore Deviation 18)Freecap I FSC-11 6.38'ODSwell Packer wl 6.5"OD Cernentrallzer i 60' a 2138'MD 19)Baker Fraq*i*EX-C Bail Actuated Sleeve(1.948"Seat fix 2.000"Ball) ': 65' • 2260"MD i 70° a 14668'MD 20)Freecap I FSC-11 6.38"ODSwell Packer wl 6.5"OD Cernentrallzer i 71 @ 14731`MD 21)Baker Fracpoint EX-C Bail Actuated Sleeve(1.886"Seat far 1.938'Ball) 122)Freecap I FSC-11 6.38`ODSwell Packer wl 6-5"OD Cementralizer 75' 14985'MD 23)Baker Fracpoint IDC-C Bail Actuated Sleeve(1.823'Seat for 1.875'Ball) 24)Freecap I FSC-11 6.38"ODSwell Packer wl 6-5"OD Cementralizer 25)Baker Fracpoint EX-C Ball Actuated Sleeve(1.761"Seat for 1.813'Ball) • . 26)Freecap I FSC-11 6.38"ODSwell Packer 6.5"OD Cementralizer 27)Baker Fracpoint EX-C Ball Actuated Sleeve(1.698"Seat fox 1.750"Ball) .t t ! 3-112" 9.3#L-90 EUE-M h"28)Freecap I FSC-11 6.38'ODSwell Packer 6.5"OD Cementralizer 29)4- ,12.6#/f TSH-563 Pre-Perforated Pup 1t 30 XO 4-14",12.6 bait,TSH-563 x IDT-M 21158' 6899' 31)4-'W CBT-M Orange Peel 21188' 8809 r Planned TOC Q \ 6-3/4-6.374"Hole TD 14.446'MD �\ , �� � _700• f- 1 78'h1D? .iti\ 6899'TVD ::: :. MR- 1111--111-111--1111--111111- cili,: 'I 1\ = - I ..:". Top Kuparuk CjlI I 15086'MD 1 6749'TVD 176.6' `""v .-- -- -- -- -.- -- ----� 4.112"12.6#L-30 TSH-563 Liner 7-5/8"29.7#L40 BTC-M Casing @ 21168'MD 16899'TVD @ 15482'MD 16819'TVD(83') Top Nechelik 15442'MD!6814'TVO(82.4°) CD3-119 APD Page 13 of 15 7 q t Printed: 17-Jan-12 Apr Dn for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 Attachment 4-Cement Summary Pilot Hole Abandonment Schematic CD3-119PB1 RKB - GL -49.1" Updated 01/10/12 fr wellhead 16"Conductor to 114' • • 10-314'45.5 ppf L-80 BTCM k, Surface Casing @ 3718'MD/2500'TVD cemented to surface 10 ppg drilling mud in hole V 13276 Kt3P+f- 13,476` ,ji `' ` Plus*2:500' Kick off plug Toa at 500 +1-132T6'MD 17 Ppq. 13776 115 hbls 1 4 hi vis - +1-15000 c_ Top Kuparuk D Reservoir at +1-15163'MD A,77 Plug#1:+/-877'Top +/-15000'MD i.§112161. } Top Dileclhelik Reservoir at � +1-15462"MD Pilot Hole @ +/-66 deg TD at+/- 15877'MD/6975 TVD CD3-119 APD rri ( Page 14 of 15 I 1 c 9 ` C .W Printed: 17-Jan-12 f;_ Apr )n for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 CD3-119 Cementing Program: 10.75"Surface Casing run to 3718'MD/2500' TVD. Cement from 3251'MD to 2751' (500' of fill)with Class G+Adds @ 15.8 PPG,and from 2751'to surface with 10.7 ppg Arctic Set Lite 3.Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1600'MD),zero excess in 16"conductor. Lead slurry: (114')X 0.6381 ft3/ft X 1.0(0%excess)=72.60 ft3 (1249'-114')X 0.3637 ft3/ft X 3.5 (250%excess)= 1444.80 ft3 above permafrost (3218'- 1249')X 0.3637 ft3/ft X 1.5 (50%excess)= 1074.2 ft3 below permafrost Total volume=72.6+ 1444.8+ 1074.2=2591.6 ft3=> 1058 Sx @ 2.45 ft3/sk ✓ System: 1058 Sx ArcticSet Lite 3 @ 10.7 PPG Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50%excess)=273 ft3 annular volume 80' X 0.5399 ft3/ft=43 ft3 shoe joint volume Total volume=273 +43 =316 ft3=>270 Sx @ 1.17 ft3/sk System: 270 Sx Class G+0.2%D046 antifoamer,0.3%D065 dispersant and 0.8%S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk Pilot Hole Cementing Requirements bk B/,* Cement Plug#1: 15877'MD to 15000'MD=877' 04 K? D" Cement with Class G+additives @ 15.8 ppg.Assume 15% excess on open hole volume. (L Slurry: 877' X 0.5319 ft3/ft X 1.15 (15%excess)=536 ft3 annular vol. ✓ ' 462 Sx @ 1.16 ft3/sk. Cement Plug#2: 13776'MD to 13276'MD=500' S 6664 Cement with Class G+additives @ 17 ppg.Assume 15% excess on open hole volume. Slurry: 500' X 0.5319 ft3tft X 1.15 (15%excess)=306 ft3 annular vol. ✓ i ? K .t S b 306 Sx @ 1.0 ft3/sk. 7.625"Intermediate Casing run to 15474'MD/6799' TVD Top of slurry is designed to be at 14,446'MD,which is 500' above the top of the Kuparuk D.Assume 40% excess annular volume. Tail Slurry: (1036')X 0.2842 ft3/ft X 1.4(40%excess)=412.2 ft3 annular vol. 80' X 0.2577 ft3/ft=20.6 ft3 shoe joint volume Total volume=412.2+20.6=432.8 ft3=>373 Sx @ 1.16 ft3/sk System: 373 Sx Class G+0.2%D046 antifoamer,+0.4%D167,0.3%D65 Accelerator,0.11%B155 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to+/-500' above the K2 interval with Class G+additives @ 15.8 ppg. Assume 40% excess annular volume Tail Slurry: (1050')X 0.2147 ft3/ft X 1.4(40%excess)=315.6 ft3 annular vol. Total volume=315.6 ft3=>272 Sx @ 1.16 ft3/sk System: 272 Sx Class G+0.2%D046 antifoamer,+0.4%D167,0.3%D65 Accelerator,0.01 gps D177 @ 15.8 PPG yielding 1.16 ft3/sk CD3-119 APD Page 15 of 15 t Printed: 17-Jan-12 AF ion for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 CD3-119 Application for Permit to Drill Document _, Drilling, -' &Wells ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005 (c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD3-119 APD Page 1 of 15 Printed: 17-Jan-12 AN )n for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 15. Attachments 9 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Well Schematic 13 Attachment 4 Cement Summary 14 MMMMNMMMMNMIMNNNNmmimimoimmimmmimmm CD3-119 APD Page 2of15 , "'• Q //'; Printed:17-Jan-12 Apr >n for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as CD3-119. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for a pilot hole for determining the top of the Nechelik sand and will be plugged back and sidetrack to a new bottom hole location for setting the intermediate casing. Location at Surface 3984.04' FNL, 1030.16' FEL, Sec 5, T12N,R5E,UM NAD 1927 RKB Elevation 49.1' AMSL Northings: 6,003,792.97 Eastings: 388,012.95 Pad Elevation 12.8' AMSL Location at Top of(Nechelik)on Pilot 2,975.23' FNL,4560.49' FEL, Sec 28,T13N,R5E,UM Hole Nad 1927 Measured Depth, RKB: 15,461.02' Northings: 6,015,295.38 Eastings: 392,540.75 Total Vertical Depth, RKB: 6,814.10' Total Vertical Depth, SS: 6,765' Location at Total Depth on p 2669.47' FNL, 4789.84' FEL, Sec 28,T13N,R5E,UM Pilot Hole Nad 1927 Measured Depth, RKB: 15,876.36 Northings: 6,015,604.42 Eastings: 392,315.02 Total Vertical Depth, RKB: 6,975.08' Total Vertical Depth, SS: 6,925.98' Location at Top of Productive Interval 2909.37' FNL,4484.99' FEL, Sec 28,T13N,R5E,UM (Heel) Nad 1927 Measured Depth, RKB: 15,481.69' Northings: 6,015,360.15 Eastings: 392,617.01 Total Vertical Depth, RKB: 6,819.17' Total Vertical Depth, SS: 6,770.07' Location at Total Depth 3586.87' FNL, 2544.92' FEL, Sec 20,T13N,R5E,UM (Toe) Nad 1927 Measured Depth, RKB: 21,177.64' Northings: 6,020,010.81 Eastings: 389,331.49 Total Vertical Depth, RKB: 6,899.1' Total Vertical Depth, SS: 6,850' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 6/ 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2)is granted. At CD3,there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please reference BOP schematics on file for Doyon 19. (j CD3-119 APD Page 3of15 Printed: 17-Jan-12 •g ,f � � l6s9t Apr Dn for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Size Csg Setting Depth GrFracture adient(lbs. Pore pressure ASP Drilling (in) MD/TVD(ft) /gal) (psi) (psi) 16" 114/ 114 10.9 52 53 10.75" 3,718/2,500 14.5 1,131 1,635 7.625" 15,481 /6,819 14.5 3,086 2,520 N/A 21,177/6,899 16.0 3,200 N/A 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 1. 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) = 1131—(0.1 x 2500')=881 psi 2. Drilling below surface casing(10 3/4") ASP=[(FG x 0.052)—0.1]D =[(14.5 x 0.052)—0.1]x 2500= 1635 psi OR ASP=FPP—(0.1 x D) =3086—(0.1 x6819')=2403 psi 3. Drilling below intermediate casing(7 5/8") ASP=FPP—(0.1 x D) =3200—(0.1 x 6899')-2510 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. CD3-119 APD Page 4 of 15 f. Printed: 17-Jan-12 44 � t t t t. F . Apr In for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.0O5(c)(6)) Casing_and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) f J (ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 42 62.5 H-40 Welded 77 Surf 114/ 114 Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTCM 3,681 Surf 3,718/2,500 1,058 sx ASLite Lead 10.7 ppg, 270 sx Class"G"Tail Slurry 15.8 ppg 1st Stage—287--sx Class G at 15.8 ppg w/ MD 7-5/8 9-7/8 29.7 L-80 BTCM 15,437 Surf 15,474/6,799 2nd 3�3 TOC sx Class G at 2 Stage—272 Class G at 15.8 ppg w/ TOC at 7,594'MD(Qannik Isolation) 3 1/2 6 3/4 9.3 L-80 8RD-M 15,240 Surf 15,394/6,807 �.N H 4 1/2 6 3/4 12.6 L-80 TSH- 563 2,787 15,394/6,807 21,168/6,899 OH,sliding sleeve,swell packer completion 7. Diverter System Information (Requirements o f 20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. This will be the 8th 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. CD3-119 APD Page 5 of 15 Printed: 17-Jan-12 a 3g� , t t r L r..,,,tt 1.,.. Apf m for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) SPUD to Intermediate Pilot Intermediate Production 13.5"surface Hole Sidetrack Hole Section— casing point— 9.875"hole 9.875" hole 6.75" 10.75" 7.625" Casing Density 8.8—10.0 ppg 9.6—11.0 ppg 10.5— 11.0 9.0 ppg .� PV 10—25 ppg 15 -22 YP 20-60 15-25 10-25 10- 15 Funnel Viscosity 100—200 15—25 Initial Gels 4—8 9- 12 IO minute gels <18 6- 10 12 -20 API Filtrate NC— 10cc/30 4-12cc/30 min <20 HPHT Fluid Loss at min (drilling) 4-12cc/30 min 12- 14 cc/30 160 (drilling) min PH 8.5-9.0 9.0- 10.0 9.0- 10.0 9.0-9.5 %bywtCaC12 Oil/Water Ratio 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 Pilot 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 11.0 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. Intermediate Sidetrack Section: The intermediate sidetrack section will be drilled with the same fresh water gel/polymer mud system as the pilot hole section.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 11.0 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 M-I SWACO's Flo-Thru polymer based drill-in fluid. Sized calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD3-119 APD Page 6 of 15 Printed: 17-Jan-12 AF on for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 9. Abnormally Pressured Formation Information (Requirements of20AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements o f 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. Move on Doyon 19. p; �C•t)µ' 2. Rig up riser,dewater cellar as needed. Blanket waiver for CD3 in place. 3. Drill 13-1/2"hole to the surface casing point as per the directional plan. (Directional Only). 4. Run and cement 10-3/4"surface casing. 5. Install and test BOPE to 3500 psi. 6. Pick up and run in hole with 9-7/8"drilling BHA to drill intermediate pilot hole. Pressure test casing to 3000 psi. 7. Drill out 20' of new hole and perform FIT to 18.0 ppg. Minimum acceptable FIT is 12.5 ppg. ° C)Aef 8. Drill 9-7/8"hole to pilot hole TD in the Nechelik formation as per directional program. (LWD Program: ` �r GR/RES/DENS/NEUT/PWD). fes° 9. POOH and lay down 9-7/8"BHA. 10. Pick up 3.5"cement stinger and RIH. a f' 11. Cement pilot hole as per program with one bottom plug and one upper kick-off plug. ' a K 12. POOH.Pick up 9-7/8 X 10-3/4"intermediate sidetrack BHA.RIH to cement plug and kick off same. 13. Drill until the 10-3/4"reamer has entered new formation.Drop ball,open reamer. 14. Drill to 7-5/8"casing point,drop reamer deactivation ball,circulate hole clean, and POOH. 15. Rig up 7-5/8"casing running equipment;change 3 ''/2'X 6"to 7-5/8"Rams and test with plug to 250 and 3500 psi. 16. Run and cement 7-5/8"casing. 17. Pump dual stage cement job to cover the Qannik and Kuparuk sands. Cement will be placed 500 feet above v and below the Qannik. O�`- 18. Swap out 7-5/8"Rams for 3 '/z"X 6"VBR. 19. Test BOPE to 3500 psi. 20. Pick up 6-3/4"drilling BHA. CD3-119 APD Page 7 of 15 Printed: 17-Jan-12 r'1") G ! NAL Ap on for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 21. Drill out 20' of new hole and perform dynamic formation integrity test to 12.5 ppg EMW. Minimum acceptable FIT is 11.0 ppg. 22. Displace 11.0 ppg LSND mud with 9.2 ppg Flo-Thru. i 23. Pick up RIH with 6-3/4"drilling assembly. (LWD Program: GR/RES/PWD/ADR). Test casing to 3500 psi. 24. Drill out and perform format}on integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. CJ`" 25. Drill to 6-3/4"section TD. Geologist will call TD and toe-up to confirm location of LCU truncation. 26. Circulate the hole clean and pull out of hole. 27. Run lower completion of 4-1/2"liner with liner top hanger/packer with swell packers. 28. Run upper completion of 3-'/2, 12.6#,L-80 tubing with SSSV,X-profile,3 GLM,and Bottom Hole Pressure gauge. 29. Space out and land hanger. 30. Install 2 way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 31. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi.Remove 2 way check. 32. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 33. Shear circulation valve in GLM&circulate tubing to diesel and install freeze protection in the annulus. 34. Set BPV and secure well. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD3-119 will be injected into a permitted annulus on the CD3 pad,or the class 1 disposal well on CD1 pad. The CD3-119 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include the Nechelik reservoir,and potentially the Qannik and Kuparuk reservoir. There will be 500' of cement fill placed above the top of the Kuparuk reservoir, along with 500' of cement above and below the Qannik reservoir as per regulations. Once CD3-119 has been drilled and completed,consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then 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)*(2500')+ 1,500 psi =3060 psi Pore Pressure = 1,131 psi Therefore Differential=3060— 1131 = 1929 psi. CD3-119 APD Page 8 of 15 Printed: 17-Jan-12 1 t� • ApI on for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 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: OD Wt Grade Range Connection Collapse 85% of Burst 85%of (ppf) Type Collapse Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 psi 2108 psi 3580 psi 3043 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Cement Summary CD3-119 APD Page 9of15 Printed: 17-Jan-12 RIt.J L Ap on for Permit to Drill,Well CD3-119 Saved: 17-Jan-12 Attachment 1 — Directional Plan CD3-119 APD Page 10 of 15 ¢ ` Printed: 17-Jan-12 ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-119 Plan: CD3-119PB1 Plan: CD3-119PB1wp11 Standard Proposal Report Permit Paic N 27 -- 13 December, 2011 'ly t�. 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TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 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: -401.28ft Longitude: 152°19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-119 Well Position +N/-S 0.00 ft Northing: 6,003,792.97 ft Latitude: 70°25'9.488 N' +E/-W 0.00 ft Easting: 388,012.95 ft Longitude: 150°54'44.282 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft - ------ - --- Wellbore Plan:CD3-119PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 12/7/2011 15.89 79.82 57,343 Design CD3-119PB1wp11 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (0) 36.30 0.00 0.00 325.00 12/13/2011 10:26:35AM Page 2 COMPASS 2003.16 Build 69 ,. I A kj) t r ConocoPhillips HALLI B U RTO N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (°) (ft) ft (ft) (ft) (1100ft) (1100ft) 0100ft) (0) 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 0.00 0.00 0.00 0.00 230.00 0.00 0.00 230.00 180.90 0.00 0.00 0.00 0.00 0.00 0.00 500.23 4.05 335.00 500.00 450.90 8.66 -4.04 1.50 1.50 0.00 335.00 650.91 6.83 347.77 650.00 600.90 22.25 -8.19 2.00 1.84 8.47 30.00 904.80 12.98 357.46 900.00 850.90 65.53 -12.65 2.50 2.42 3.82 20.00 1,113.37 19.76 357.46 1,100.00 1,050.90 124.21 -15.26 3.25 3.25 0.00 0.00 1,449.23 33.16 359.58 1,400.00 1,350.90 273.45 -18.45 4.00 3.99 0.63 5.00 2,298.71 66.63 25.00 1,944.40 1,895.30 881.87 150.96 4.50 3.94 2.99 39.55 3,298.71 66.63 25.00 2,341.07 2,291.97 1,713.83 538.91 0.00 0.00 0.00 0.00 3,450.91 68.00 30.58 2,399.81 2,350.71 1,837.97 604.38 3.50 0.90 3.67 76.19 12,626.28 68.00 30.58 5,836.96 5,787.86 9,162.03 4,932.36 0.00 0.00 0.00 0.00 13,476.00 68.08 358.45 6,162.07 6,112.97 9,912.08 5,126.50 3.50 0.01 -3.78 -96.00 13,650.23 73.00 356.59 6,220.10 6,171.00 10,076.15 5,119.36 3.00 2.82 -1.07 -20.00 14,717.18 70.37 322.93 6,564.29 6,515.19 11,010.76 4,777.14 3.00 -0.25 -3.15 -100.00 '.. 15,461.02 70.38 322.99 6,814.10 6,765.00 11,570.04 4,355.12 0.01 0.00 0.01 78.54 15,676.73 66.07 322.99 6,894.10 6,845.00 11,729.97 4,234.57 2.00 -2.00 0.00 180.00 15,876.36 66.07 322.99 6,975.08 6,925.98 11,875.68 4,124.75 0.00 0.00 0.000.00 12/13/2011 10:26:35AMIIRIGNAL Page COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/.W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) -12.80 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 100.00 0.00 0.00 100.00 50.90 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 200.00 0.00 0.00 200.00 150.90 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 230.00 0.00 0.00 230.00 180.90 0.00 0.00 6,003,792.97 388,012.95 0.00 0.00 Start Build 1.50 300.00 1.05 335.00 300.00 250.90 0.58 -0.27 6,003,793.55 388,012.69 1.50 0.63 400.00 2.55 335.00 399.94 350.84 3.43 -1.60 6,003,796.42 388,011.40 1.50 3.72 500.00 4.05 335.00 499.78 450.68 8.64 -4.03 6,003,801.67 388,009.05 1.50 9.39 500.23 4.05 335.00 500.00 450.90 8.66 -4.04 6,003,801.69 388,009.04 1.50 9.41 Start DLS 2.00 TFO 30.00 600.00 5.87 344.81 599.40 550.30 16.78 -6.86 6,003,809.85 388,006.34 2.00 17.68 650.91 6.83 347.77 650.00 600.90 22.25 -8.19 6,003,815.33 388,005.10 2.00 22.92 Start DLS 2.50 TFO 20.00 700.00 8.00 350.79 698.67 649.57 28.47 -9.35 6,003,821.57 388,004.02 2.50 28.69 800.00 10.41 354.83 797.38 748.28 44.34 -11.28 6,003,837.47 388,002.34 2.50 42.79 900.00 12.86 357.36 895.32 846.22 64.46 -12.61 6,003,857.60 388,001.31 2.50 60.03 904.80 12.98 357.46 900.00 850.90 65.53 -12.65 6,003,858.67 388,001.28 2.50 60.94 Start Build 3.25 1,000.00 16.07 357.46 992.14 943.04 89.38 -13.71 6,003,882.53 388,000.58 3.25 81.08 1,100.00 19.32 357.46 1,087.40 1,038.30 119.74 -15.06 6,003,912.91 387,999.69 3.25 106.72 1,113.37 19.76 357.46 1,100.00 1,050.90 124.21 -15.26 6,003,917.38 387,999.56 3.25 110.50 Start DLS 4.00 TFO 5.00 1,200.00 23.21 358.23 1,180.60 1,131.50 155.91 -16.43 6,003,949.09 387,998.86 4.00 137.14 1,249.89 25.20 358.58 1,226.10 1,177.00 176.35 -17.00 6,003,969.54 387,998.60 4.00 154.21 Base Permafrost 1,300.00 27.20 358.88 1,271.06 1,221.96 198.47 -17.49 6,003,991.66 387,998.44 4.00 172.61 1,400.00 31.19 359.38 1,358.34 1,309.24 247.24 -18.22 6,004,040.43 387,998.44 4.00 212.98 1,449.23 33.16 359.58 1,400.00 1,350.90 273.45 -18.45 6,004,066.64 387,998.60 4.00 234.58 Start DLS 4.50 TFO 39.55 1,500.00 34.95 2.12 1,442.07 1,392.97 301.87 -18.02 6,004,095.05 387,999.46 4.50 257.61 1,600.00 38.61 6.51 1,522.17 1,473.07 361.52 -13.42 6,004,154.62 388,004.96 4.50 303.84 1,700.00 42.40 10.23 1,598.20 1,549.10 425.73 -3.89 6,004,218.67 388,015.45 4.50 350.97 1,800.00 46.30 13.44 1,669.70 1,620.60 494.10 10.51 6,004,286.82 388,030.87 4.50 398.72 1,900.00 50.28 16.26 1,736.23 1,687.13 566.22 29.69 6,004,358.63 388,051.13 4.50 446.79 2,000.00 54.32 18.77 1,797.37 1,748.27 641.64 53.54 6,004,433.68 388,076.10 4.50 494.89 2,100.00 58.41 21.03 1,852.76 1,803.66 719.89 81.91 6,004,511.48 388,105.64 4.50 542.72 2,200.00 62.53 23.10 1,902.04 1,852.94 800.49 114.61 6,004,591.58 388,139.55 4.50 589.98 2,298.71 66.63 25.00 1,944.40 1,895.30 881.87 150.96 6,004,672.40 388,177.11 4.50 635.80 Start 1000.00 hold at 2298.71 MD 2,300.00 66.63 25.00 1,944.91 1,895.81 882.94 151.46 6,004,673.46 388,177.63 0.00 636.39 2,400.00 66.63 25.00 1,984.58 1,935.48 966.14 190.26 6,004,756.06 388,217.66 0.00 682.29 2,500.00 66.63 25.00 2,024.25 1,975.15 1,049.33 229.05 6,004,838.66 388,257.70 0.00 728.18 2,600.00 66.63 25.00 2,063.91 2,014.81 1,132.53 267.85 6,004,921.25 388,297.73 0.00 774.08 2,700.00 66.63 25.00 2,103.58 2,054.48 1,215.72 306.64 6,005,003.85 388,337.77 0.00 819.98 2,800.00 66.63 25.00 2,143.25 2,094.15 1,298.92 345.44 6,005,086.45 388,377.80 0.00 865.88 12/13/2011 10:26:35AM Page 4 COMPASS 2003.16 Build 69 OR1Gfty \ f ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 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) 2,133.81 2,900.00 66.63 25.00 2,182.91 2,133.81 1,382.12 384.23 6,005,169.05 388,417.84 0.00 911.78 3,000.00 66.63 25.00 2,222.58 2,173.48 1,465.31 423.03 6,005,251.64 388,457.87 0.00 957.67 3,100.00 66.63 25.00 2,262.25 2,213.15 1,548.51 461.82 6,005,334.24 388,497.91 0.00 1,003.57 3,200.00 66.63 25.00 2,301.91 2,252.81 1,631.70 500.62 6,005,416.84 388,537.94 0.00 1,049.47 3,293.74 66.63 25.00 2,339.10 2,290.00 1,709.69 536.98 6,005,494.27 388,575.47 0.00 1,092.50 C-40 3,298.71 66.63 25.00 2,341.07 2,291.97 1,713.83 538.91 6,005,498.37 388,577.46 0.00 1,094.78 Start DLS 3.50 TFO 76.19 3,300.00 66.64 25.05 2,341.58 2,292.48 1,714.90 539.41 6,005,499.43 388,577.98 3.50 1,095.37 3,400.00 67.52 28.73 2,380.54 2,331.44 1,797.02 581.06 6,005,580.92 388,620.85 3.50 1,138.75 3,450.91 68.00 30.58 2,399.81 2,350.71 1,837.97 604.38 6,005,621.51 388,644.78 3.50 1,158.92 Start 9175.37 hold at 3450.91 MD 3,500.00 68.00 30.58 2,418.20 2,369.10 1,877.16 627.53 6,005,660.34 388,668.51 0.00 1,177.74 3,600.00 68.00 30.58 2,455.66 2,406.56 1,956.98 674.70 6,005,739.44 388,716.87 0.00 1,216.07 3,700.00 68.00 30.58 2,493.12 2,444.02 2,036.80 721.87 6,005,818.54 388,765.23 0.00 1,254.40 3,718.37 68.00 30.58 2,500.00 2,450.90 2,051.47 730.54 6,005,833.07 388,774.11 0.00 1,261.45 10-3/4"x 13-1/2" 3,769.36 68.00 30.58 2,519.10 2,470.00 2,092.17 754.59 6,005,873.40 388,798.77 0.00 1,280.99 C-30 3,800.00 68.00 30.58 2,530.58 2,481.48 2,116.63 769.04 6,005,897.64 388,813.59 0.00 1,292.73 3,900.00 68.00 30.58 2,568.04 2,518.94 2,196.45 816.21 6,005,976.74 388,861.94 0.00 1,331.07 4,000.00 68.00 30.58 2,605.50 2,556.40 2,276.27 863.38 6,006,055.84 388,910.30 0.00 1,369.40 4,100.00 68.00 30.58 2,642.96 2,593.86 2,356.09 910.55 6,006,134.94 388,958.66 0.00 1,407.73 4,200.00 68.00 30.58 2,680.42 2,631.32 2,435.92 957.72 6,006,214.04 389,007.02 0.00 1,446.06 4,300.00 68.00 30.58 2,717.88 2,668.78 2,515.74 1,004.89 6,006,293.14 389,055.37 0.00 1,484.39 4,400.00 68.00 30.58 2,755.34 2,706.24 2,595.56 1,052.06 6,006,372.24 389,103.73 0.00 1,522.73 4,500.00 68.00 30.58 2,792.80 2,743.70 2,675.39 1,099.23 6,006,451.34 389,152.09 0.00 1,561.06 4,600.00 68.00 30.58 2,830.26 2,781.16 2,755.21 1,146.40 6,006,530.44 389,200.45 0.00 1,599.39 4,700.00 68.00 30.58 2,867.72 2,818.62 2,835.03 1,193.57 6,006,609.54 389,248.81 0.00 1,637.72 4,800.00 68.00 30.58 2,905.18 2,856.08 2,914.86 1,240.74 6,006,688.64 389,297.16 0.00 1,676.05 4,837.15 68.00 30.58 2,919.10 2,870.00 2,944.51 1,258.26 6,006,718.02 389,315.13 0.00 1,690.29 C-20 4,900.00 68.00 30.58 2,942.64 2,893.54 2,994.68 1,287.91 6,006,767.74 389,345.52 0.00 1,714.39 5,000.00 68.00 30.58 2,980.11 2,931.01 3,074.50 1,335.08 6,006,846.83 389,393.88 0.00 1,752.72 5,100.00 68.00 30.58 3,017.57 2,968.47 3,154.33 1,382.25 6,006,925.93 389,442.24 0.00 1,791.05 5,200.00 68.00 30.58 3,055.03 3,005.93 3,234.15 1,429.42 6,007,005.03 389,490.59 0.00 1,829.38 5,300.00 68.00 30.58 3,092.49 3,043.39 3,313.97 1,476.58 6,007,084.13 389,538.95 0.00 1,867.71 5,400.00 68.00 30.58 3,129.95 3,080.85 3,393.79 1,523.75 6,007,163.23 389,587.31 0.00 1,906.04 5,500.00 68.00 30.58 3,167.41 3,118.31 3,473.62 1,570.92 6,007,242.33 389,635.67 0.00 1,944.38 5,600.00 68.00 30.58 3,204.87 3,155.77 3,553.44 1,618.09 6,007,321.43 389,684.02 0.00 1,982.71 5,700.00 68.00 30.58 3,242.33 3,193.23 3,633.26 1,665.26 6,007,400.53 389,732.38 0.00 2,021.04 5,800.00 68.00 30.58 3,279.79 3,230.69 3,713.09 1,712.43 6,007,479.63 389,780.74 0.00 2,059.37 5,900.00 68.00 30.58 3,317.25 3,268.15 3,792.91 1,759.60 6,007,558.73 389,829.10 0.00 2,097.70 6,000.00 68.00 30.58 3,354.71 3,305.61 3,872.73 1,806.77 6,007,637.83 389,877.46 0.00 2,136.04 6,100.00 68.00 30.58 3,392.17 3,343.07 3,952.56 1,853.94 6,007,716.93 389,925.81 0.00 2,174.37 12/13/2011 10:26:35AM Page 5 COMPASS 2003.16 Build 69 0 3 ! Gf ! 1.. ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (1 (ft) ft (ft) (ft) (ft) (ft) 3,380.53 6,200.00 68.00 30.58 3,429.63 3,380.53 4,032.38 1,901.11 6,007,796.03 389,974.17 0.00 2,212.70 6,300.00 68.00 30.58 3,467.09 3,417.99 4,112.20 1,948.28 6,007,875.13 390,022.53 0.00 2,251.03 6,400.00 68.00 30.58 3,504.55 3,455.45 4,192.03 1,995.45 6,007,954.23 390,070.89 0.00 2,289.36 6,500.00 68.00 30.58 3,542.02 3,492.92 4,271.85 2,042.62 6,008,033.33 390,119.24 0.00 2,327.69 6,600.00 68.00 30.58 3,579.48 3,530.38 4,351.67 2,089.79 6,008,112.43 390,167.60 0.00 2,366.03 6,700.00 68.00 30.58 3,616.94 3,567.84 4,431.50 2,136.96 6,008,191.53 390,215.96 0.00 2,404.36 6,800.00 68.00 30.58 3,654.40 3,605.30 4,511.32 2,184.13 6,008,270.63 390,264.32 0.00 2,442.69 6,900.00 68.00 30.58 3,691.86 3,642.76 4,591.14 2,231.30 6,008,349.73 390,312.67 0.00 2,481.02 7,000.00 68.00 30.58 3,729.32 3,680.22 4,670.96 2,278.47 6,008,428.83 390,361.03 0.00 2,519.35 7,100.00 68.00 30.58 3,766.78 3,717.68 4,750.79 2,325.64 6,008,507.93 390,409.39 0.00 2,557.69 7,200.00 68.00 30.58 3,804.24 3,755.14 4,830.61 2,372.81 6,008,587.03 390,457.75 0.00 2,596.02 7,300.00 68.00 30.58 3,841.70 3,792.60 4,910.43 2,419.98 6,008,666.13 390,506.10 0.00 2,634.35 7,400.00 68.00 30.58 3,879.16 3,830.06 4,990.26 2,467.15 6,008,745.23 390,554.46 0.00 2,672.68 7,500.00 68.00 30.58 3,916.62 3,867.52 5,070.08 2,514.32 6,008,824.33 390,602.82 0.00 2,711.01 7,600.00 68.00 30.58 3,954.08 3,904.98 5,149.90 2,561.49 6,008,903.43 390,651.18 0.00 2,749.35 7,600.05 68.00 30.58 3,954.10 3,905.00 5,149.94 2,561.51 6,008,903.46 390,651.20 0.00 2,749.36 K-3 7,700.00 68.00 30.58 3,991.54 3,942.44 5,229.73 2,608.66 6,008,982.53 390,699.54 0.00 2,787.68 7,800.00 68.00 30.58 4,029.00 3,979.90 5,309.55 2,655.83 6,009,061.63 390,747.89 0.00 2,826.01 7,900.00 68.00 30.58 4,066.46 4,017.36 5,389.37 2,703.00 6,009,140.73 390,796.25 0.00 2,864.34 8,000.00 68.00 30.58 4,103.93 4,054.83 5,469.20 2,750.17 6,009,219.83 390,844.61 0.00 2,902.67 8,000.47 68.00 30.58 4,104.10 4,055.00 5,469.57 2,750.39 6,009,220.19 390,844.83 0.00 2,902.85 K-3 Basal 8,093.90 68.00 30.58 4,139.10 4,090.00 5,544.15 2,794.46 6,009,294.10 390,890.02 0.00 2,938.67 K-2 8,100.00 68.00 30.58 4,141.39 4,092.29 5,549.02 2,797.33 6,009,298.93 390,892.97 0.00 2,941.00 8,200.00 68.00 30.58 4,178.85 4,129.75 5,628.84 2,844.50 6,009,378.02 390,941.32 0.00 2,979.34 8,300.00 68.00 30.58 4,216.31 4,167.21 5,708.66 2,891.67 6,009,457.12 390,989.68 0.00 3,017.67 8,387.54 68.00 30.58 4,249.10 4,200.00 5,778.54 2,932.97 6,009,526.37 391,032.01 0.00 3,051.22 K-2 Basal 8,400.00 68.00 30.58 4,253.77 4,204.67 5,788.49 2,938.84 6,009,536.22 391,038.04 0.00 3,056.00 8,500.00 68.00 30.58 4,291.23 4,242.13 5,868.31 2,986.01 6,009,615.32 391,086.40 0.00 3,094.33 8,600.00 68.00 30.58 4,328.69 4,279.59 5,948.13 3,033.18 6,009,694.42 391,134.75 0.00 3,132.66 8,700.00 68.00 30.58 4,366.15 4,317.05 6,027.96 3,080.35 6,009,773.52 391,183.11 0.00 3,171.00 8,800.00 68.00 30.58 4,403.61 4,354.51 6,107.78 3,127.52 6,009,852.62 391,231.47 0.00 3,209.33 8,900.00 68.00 30.58 4,441.07 4,391.97 6,187.60 3,174.69 6,009,931.72 391,279.83 0.00 3,247.66 9,000.00 68.00 30.58 4,478.53 4,429.43 6,267.43 3,221.86 6,010,010.82 391,328.19 0.00 3,285.99 9,100.00 68.00 30.58 4,515.99 4,466.89 6,347.25 3,269.03 6,010,089.92 391,376.54 0.00 3,324.32 9,200.00 68.00 30.58 4,553.45 4,504.35 6,427.07 3,316.20 6,010,169.02 391,424.90 0.00 3,362.65 9,300.00 68.00 30.58 4,590.91 4,541.81 6,506.90 3,363.37 6,010,248.12 391,473.26 0.00 3,400.99 9,400.00 68.00 30.58 4,628.37 4,579.27 6,586.72 3,410.54 6,010,327.22 391,521.62 0.00 3,439.32 9,500.00 68.00 30.58 4,665.83 4,616.73 6,666.54 3,457.71 6,010,406.32 391,569.97 0.00 3,477.65 9,600.00 68.00 30.58 4,703.30 4,654.20 6,746.36 3,504.88 6,010,485.42 391,618.33 0.00 3,515.98 9,700.00 68.00 30.58 4,740.76 4,691.66 6,826.19 3,552.05 6,010,564.52 391,666.69 0.00 3,554.31 9,800.00 68.00 30.58 4,778.22 4,729.12 6,906.01 3,599.22 6,010,643.62 391,715.05 0.00 3,592.65 12/13/2011 10:26:35AM Page 6 COMPASS 2003.16 Build 69 U R t k ConocoPhillips HALLI B U RTO N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature . Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Planned Survey I 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) 4,766.58 9,900.00 68.00 30.58 4,815.68 4,766.58 6,985.83 3,646.39 6,010,722.72 391,763.40 0.00 3,630.98 10,000.00 68.00 30.58 4,853.14 4,804.04 7,065.66 3,693.56 6,010,801.82 391,811.76 0.00 3,669.31 10,100.00 68.00 30.58 4,890.60 4,841.50 7,145.48 3,740.73 6,010,880.92 391,860.12 0.00 3,707.64 10,200.00 68.00 30.58 4,928.06 4,878.96 7,225.30 3,787.90 6,010,960.02 391,908.48 0.00 3,745.97 10,300.00 68.00 30.58 4,965.52 4,916.42 7,305.13 3,835.07 6,011,039.12 391,956.83 0.00 3,784.30 10,400.00 68.00 30.58 5,002.98 4,953.88 7,384.95 3,882.24 6,011,118.22 392,005.19 0.00 3,822.64 10,500.00 68.00 30.58 5,040.44 4,991.34 7,464.77 3,929.41 6,011,197.32 392,053.55 0.00 3,860.97 10,600.00 68.00 30.58 5,077.90 5,028.80 7,544.60 3,976.58 6,011,276.42 392,101.91 0.00 3,899.30 10,700.00 68.00 30.58 5,115.36 5,066.26 7,624.42 4,023.75 6,011,355.52 392,150.27 0.00 3,937.63 10,800.00 68.00 30.58 5,152.82 5,103.72 7,704.24 4,070.91 6,011,434.62 392,198.62 0.00 3,975.96 10,900.00 68.00 30.58 5,190.28 5,141.18 7,784.06 4,118.08 6,011,513.72 392,246.98 0.00 4,014.30 11,000.00 68.00 30.58 5,227.74 5,178.64 7,863.89 4,165.25 6,011,592.82 392,295.34 0.00 4,052.63 11,100.00 68.00 30.58 5,265.21 5,216.11 7,943.71 4,212.42 6,011,671.92 392,343.70 0.00 4,090.96 11,200.00 68.00 30.58 5,302.67 5,253.57 8,023.53 4,259.59 6,011,751.02 392,392.05 0.00 4,129.29 11,300.00 68.00 30.58 5,340.13 5,291.03 8,103.36 4,306.76 6,011,830.12 392,440.41 0.00 4,167.62 11,400.00 68.00 30.58 5,377.59 5,328.49 8,183.18 4,353.93 6,011,909.21 392,488.77 0.00 4,205.96 11,500.00 68.00 30.58 5,415.05 5,365.95 8,263.00 4,401.10 6,011,988.31 392,537.13 0.00 4,244.29 11,600.00 68.00 30.58 5,452.51 5,403.41 8,342.83 4,448.27 6,012,067.41 392,585.48 0.00 4,282.62 11,700.00 68.00 30.58 5,489.97 5,440.87 8,422.65 4,495.44 6,012,146.51 392,633.84 0.00 4,320.95 11,800.00 68.00 30.58 5,527.43 5,478.33 8,502.47 4,542.61 6,012,225.61 392,682.20 0.00 4,359.28 11,900.00 68.00 30.58 5,564.89 5,515.79 8,582.30 4,589.78 6,012,304.71 392,730.56 0.00 4,397.61 12,000.00 68.00 30.58 5,602.35 5,553.25 8,662.12 4,636.95 6,012,383.81 392,778.92 0.00 4,435.95 12,100.00 68.00 30.58 5,639.81 5,590.71 8,741.94 4,684.12 6,012,462.91 392,827.27 0.00 4,474.28 12,200.00 68.00 30.58 5,677.27 5,628.17 8,821.76 4,731.29 6,012,542.01 392,875.63 0.00 4,512.61 12,298.31 68.00 30.58 5,714.10 5,665.00 8,900.24 4,777.66 6,012,619.77 392,923.17 0.00 4,550.29 Albian 97 12,300.00 68.00 30.58 5,714.73 5,665.63 8,901.59 4,778.46 6,012,621.11 392,923.99 0.00 4,550.94 12,400.00 68.00 30.58 5,752.19 5,703.09 8,981.41 4,825.63 6,012,700.21 392,972.35 0.00 4,589.27 12,500.00 68.00 30.58 5,789.65 5,740.55 9,061.23 4,872.80 6,012,779.31 393,020.70 0.00 4,627.61 12,600.00 68.00 30.58 5,827.12 5,778.02 9,141.06 4,919.97 6,012,858.41 393,069.06 0.00 4,665.94 12,626.28 68.00 30.58 5,836.96 5,787.86 9,162.03 4,932.36 6,012,879.20 393,081.77 0.00 4,676.01 Start DLS 3.50 TFO-96.00 12,700.00 67.75 27.81 5,864.73 5,815.63 9,221.64 4,965.67 6,012,938.30 393,115.96 3.50 4,705.74 12,800.00 67.49 24.03 5,902.81 5,853.71 9,304.79 5,006.09 6,013,020.82 393,157.62 3.50 4,750.67 12,900.00 67.32 20.25 5,941.23 5,892.13 9,390.29 5,040.87 6,013,105.78 393,193.68 3.50 4,800.75 13,000.00 67.24 16.45 5,979.86 5,930.76 9,477.82 5,069.91 6,013,192.86 393,224.02 3.50 4,855.80 13,023.88 67.24 15.55 5,989.10 5,940.00 9,498.99 5,075.98 6,013,213.93 393,230.41 3.50 4,869.66 Albian 96 13,100.00 67.25 12.66 6,018.55 5,969.45 9,567.06 5,093.08 6,013,281.73 393,248.53 3.50 4,915.61 13,200.00 67.35 8.86 6,057.15 6,008.05 9,657.67 5,110.30 6,013,372.07 393,267.10 3.50 4,979.95 13,300.00 67.54 5.08 6,095.52 6,046.42 9,749.32 5,121.50 6,013,463.53 393,279.68 3.50 5,048.60 13,400.00 67.81 1.31 6,133.52 6,084.42 9,841.65 5,126.65 6,013,555.77 393,286.21 3.50 5,121.28 13,476.00 68.08 358.45 6,162.07 6,112.97 9,912.08 5,126.50 6,013,626.19 393,287.12 3.50 5,179.06 Trough:DLS 3.00 TFO-20.00-7-5/8"X 9-7/8" 13,500.00 68.75 358.19 6,170.89 6,121.79 9,934.39 5,125.85 6,013,648.50 393,286.80 3.00 5,197.71 12/13/2011 10:26:35AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTGIN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB 1 wp 11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +Ei W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 6,150.00 13,582.13 71.07 357.30 6,199.10 6,150.00 10,011.46 5,122.81 6,013,725.60 393,284.92 3.00 5,262.59 ShaleAboveHRZ 13,600.00 71.58 357.11 6,204.82 6,155.72 10,028.37 5,121.99 6,013,742.52 393,284.35 3.00 5,276.91 13,650.23 73.00 356.59 6,220.10 6,171.00 10,076.15 5,119.36 6,013,790.33 393,282.44 3.00 5,317.56 Start DLS 3.00 TFO-100.00 13,700.00 72.75 355.05 6,234.76 6,185.66 10,123.58 5,115.89 6,013,837.80 393,279.68 3.00 5,358.40 13,800.00 72.27 351.94 6,264.82 6,215.72 10,218.33 5,105.08 6,013,932.69 393,270.30 3.00 5,442.21 13,900.00 71.85 348.82 6,295.63 6,246.53 10,312.11 5,089.19 6,014,026.70 393,255.81 3.00 5,528.15 14,000.00 71.47 345.68 6,327.10 6,278.00 10,404.68 5,068.24 6,014,119.56 393,236.26 3.00 5,615.99 14,100.00 71.15 342.53 6,359.14 6,310.04 10,495.78 5,042.31 6,014,211.03 393,211.70 3.00 5,705.49 14,200.00 70.88 339.37 6,391.68 6,342.58 10,585.15 5,011.46 6,014,300.84 393,182.20 3.00 5,796.39 14,300.00 70.67 336.20 6,424.61 6,375.51 10,672.55 4,975.77 6,014,388.77 393,147.83 3.00 5,888.46 14,373.75 70.55 333.86 6,449.10 6,400.00 10,735.61 4,946.41 6,014,452.25 393,119.42 3.00 5,956.95 ShaleAboveHRZBase 14,400.00 70.51 333.03 6,457.85 6,408.75 10,757.75 4,935.35 6,014,474.55 393,108.69 3.00 5,981.43 14,493.41 70.41 330.06 6,489.10 6,440.00 10,835.13 4,893.41 6,014,552.55 393,067.92 3.00 6,068.88 Top HRZ 14,500.00 70.40 329.85 6,491.31 6,442.21 10,840.51 4,890.30 6,014,557.97 393,064.89 3.00 6,075.06 14,600.00 70.36 326.66 6,524.90 6,475.80 10,920.60 4,840.75 6,014,638.79 393,016.55 3.00 6,169.09 14,700.00 70.36 323.48 6,558.52 6,509.42 10,997.80 4,786.83 6,014,716.78 392,963.80 3.00 6,263.26 14,717.18 70.37 322.93 6,564.29 6,515.19 11,010.76 4,777.14 6,014,729.88 392,954.31 3.00 6,279.43 Start DLS 0.01 TFO-13.50 14,800.00 70.37 322.94 6,592.11 6,543.01 11,073.00 4,730.12 6,014,792.82 392,908.23 0.01 6,357.39 14,900.00 70.37 322.95 6,625.70 6,576.60 11,148.17 4,673.36 6,014,868.82 392,852.61 0.01 6,451.52 14,954.78 70.37 322.94 6,644.10 6,595.00 11,189.34 4,642.27 6,014,910.46 392,822.14 0.00 6,503.08 Base HRZ 15,000.00 70.37 322.95 6,659.29 6,610.19 11,223.34 4,616.61 6,014,944.84 392,797.00 0.02 6,545.65 15,067.92 70.38 322.96 6,682.10 6,633.00 11,274.41 4,578.07 6,014,996.47 392,759.23 0.01 6,609.58 K-1 15,100.00 70.38 322.96 6,692.87 6,643.77 11,298.53 4,559.87 6,015,020.86 392,741.40 0.01 6,639.78 15,163.21 70.38 322.98 6,714.10 6,665.00 11,346.06 4,524.01 6,015,068.91 392,706.26 0.02 6,699.28 Top Kuparuk D 15,200.00 70.38 322.97 6,726.46 6,677.36 11,373.72 4,503.14 6,015,096.88 392,685.81 0.01 6,733.91 15,267.43 70.38 322.98 6,749.10 6,700.00 11,424.43 4,464.89 6,015,148.16 392,648.33 0.01 6,797.39 Top Kuparuk C 15,282.32 70.38 322.98 6,754.10 6,705.00 11,435.63 4,456.45 6,015,159.48 392,640.05 0.01 6,811.41 LCU 15,300.00 70.38 322.98 6,760.04 6,710.94 11,448.92 4,446.42 6,015,172.92 392,630.23 0.00 6,828.05 15,400.00 70.38 322.99 6,793.61 6,744.51 11,524.14 4,389.71 6,015,248.97 392,574.66 0.01 6,922.18 15,416.34 70.38 322.97 6,799.10 6,750.00 11,536.43 4,380.45 6,015,261.40 392,565.58 0.10 6,937.57 Base Nuiqsut 15,461.02 70.38 322.99 6,814.10 6,765.00 11,570.03 4,355.11 6,015,295.38 392,540.75 0.04 6,979.63 Top Nechelik-CD3-119PB1 22Nov11 T1 (copy) 15,461.79 70.37 322.99 6,814.36 6,765.26 11,570.61 4,354.68 6,015,295.96 392,540.33 1.98 6,980.35 Start DLS 2.00 TFO 180.00 15,500.00 69.60 322.99 6,827.44 6,778.34 11,599.28 4,333.07 6,015,324.95 392,519.15 2.00 7,016.23 12/13/2011 10:26:35AM Page 8 COMPASS 2003.16 Build 69 ` ) 13 M 4 ConocoPhillips HALLI B U RTO N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section I (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,814.82 15,600.00 67.60 322.99 6,863.92 6,814.82 11,673.63 4,277.03 6,015,400.13 392,464.24 2.00 7,109.28 ' 15,664.34 66.32 322.99 6,889.10 6,840.00 11,720.92 4,241.40 6,015,447.94 392,429.32 2.00 7,168.45 Base Nechelik 15,676.73 66.07 322.99 6,894.10 6,845.00 11,729.97 4,234.57 6,015,457.09 392,422.64 2.00 7,179.78 15,677.86 66.07 322.99 6,894.56 6,845.46 11,730.79 4,233.96 6,015,457.92 392,422.03 0.00 7,180.80 Start 199.63 hold at 15677.86 MD 15,700.00 66.07 322.99 6,903.54 6,854.44 11,746.95 4,221.77 6,015,474.26 392,410.09 0.00 7,201.03 15,800.00 66.07 322.99 6,944.10 6,895.00 11,819.95 4,166.76 6,015,548.07 392,356.19 0.00 7,292.38 15,876.36 66.07 322.99 6,975.08 6,925.98 11,875.68 4,124.75 6,015,604.42 392,315.02 0.00 7,362.13 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-119PB1 22Nov11 T1 (copy) 0.00 0.00 6,814.10 11,570.04 4,355.12 6,015,295.38 392,540.76 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (") 3,718.37 2,500.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 13,476.00 6,162.07 7-5/8"X 9-7/8" 7-5/8 9-7/8 12/13/2011 10:26:35AM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119PB1 Design: CD3-119PB1wp11 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (1 14,373.75 6,449.10 ShaleAboveHRZBase 8,000.47 4,104.10 K-3 Basal 4,837.15 2,919.10 C-20 12,298.31 5,714.10 Albian 97 15,163.21 6,714.10 Top Kuparuk D 7,600.05 3,954.10 K-3 15,067.92 6,682.10 K-1 13,023.88 5,989.10 Albian 96 3,293.74 2,339.10 C-40 15,664.34 6,889.10 Base Nechelik 13,582.13 6,199.10 ShaleAboveHRZ 8,093.90 4,139.10 K-2 15,461.02 6,814.10 Top Nechelik 14,493.41 6,489.10 Top HRZ 15,267.43 6,749.10 Top Kuparuk C 3,769.36 2,519.10 C-30 14,954.78 6,644.10 Base HRZ 8,387.54 4,249.10 K-2 Basal 1,249.89 1,226.10 Base Permafrost 15,282.32 6,754.10 LCU 15,416.34 6,799.10 Base Nuiqsut Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 230.00 230.00 0.00 0.00 Start Build 1.50 500.23 500.00 8.66 -4.04 Start DLS 2.00 TFO 30.00 650.91 650.00 22.25 -8.19 Start DLS 2.50 TFO 20.00 904.80 900.00 65.53 -12.65 Start Build 3.25 1,113.37 1,100.00 124.21 -15.26 Start DLS 4.00 TFO 5.00 1,449.23 1,400.00 273.45 -18.45 Start DLS 4.50 TFO 39.55 2,298.71 1,944.40 881.87 150.96 Start 1000.00 hold at 2298.71 MD 3,298.71 2,341.07 1,713.83 538.91 Start DLS 3.50 TFO 76.19 3,450.91 2,399.81 1,837.97 604.38 Start 9175.37 hold at 3450.91 MD 12,626.28 5,836.96 9,162.03 4,932.36 Start DLS 3.50 TFO-96.00 13,476.00 6,162.07 9,912.08 5,126.50 Trough:DLS 3.00 TFO-20.00 13,650.23 6,220.10 10,076.15 5,119.36 Start DLS 3.00 TFO-100.00 14,717.18 6,564.29 11,010.76 4,777.14 Start DLS 0.01 TFO-13.50 15,461.79 6,814.36 11,570.61 4,354.68 Start DLS 2.00 TFO 180.00 15,677.86 6,894.56 11,730.79 4,233.96 Start 199.63 hold at 15677.86 MD 15,877.48 TD at 15877.48 12/13/2011 10:26:35AM Page 10 COMPASS 2003.16 Build 69 tli W 0 H a N 3 C c mL J J > 4 L L cri• t CI) -a m Z £ lin a) c a O _ _ • 0 3 � ,_, o m zo a 20a cu ^y ui y 2 c M a o CD . 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E. 0 I I 1 I 1111 1111 I 1 I 1111 I 1 III 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND CD3-107,CD3-107,CD3-107 V7 -X- CD3-121,CD3-121,CD3-121 VO -e_ CD3-301,CD3-301A,CD3-301A VO $- CD3-107,CD3-107L1,CD3-107L1 VO -0- CD3-122,CD3-122,CD3-122 VO -I- CD3-301,CD3-301APB1,CD3-301APB1 VO X CD3-108,CD3-108,CD3-108 V14 -F CD3-123,CD3-123,CD3-123 VO -Ar- CD3-301,CD3-301PB1,CD3-301PB1 V1 0 CD3-109,CD3-109,CD3-109 V5 -e- CD3-124,CD3-124,CD3-124 VO -A- CD3-302,CD3-302A,CD3-302A VO f CD3-110,CD3-110,CD3-110 V12 -X- CD3-125,CD3-125,CD3-125 VO -A-- CD3-316,CD3-316,CD3-316 VO -'- CD3-111,CD3-111,CD3-111 V7 _e_ CD3-125,CD3-125PB1,CD3-125PB1 VO -8- CO3-316,CD3-316A.CD3-316A VO $- CD3-111,CO3-111L7,CD3-111L1 VI -48.-- CD3-125,CD3-125PB1(surface).CD3-125PB1(surface)VO - CD3-316,CD3-316APB1,CD3-316APB1 VO A CD3-112,CD3-112,CD3-112 V3 $ CD3-127,CD3-127PB1,CD3-127PB1 VO -I- Plan:CD3-119,Plan'.CD3-119,CD3-119wp11 VO -4)- CD3-113,CD3-113,CD3-113 V6 CD3-127,Plan:CD3-127,CD3-127wp05 VO $ Plan:CD3-120,Plan:CD3-120,CD3-120wp08 work in progress VO X CO3-114,CD3-114,CD3-114 V14 -X- CD3-128,CD3-128,CO3-128 VO -X- Plan:CD3-126,Plan:CD3-126.CD3-126wp04 VO 0 CD3-115,CD3-115,CD3-115 VO -A- CD3-128,CD3-128,CO3-128wp07 VO -I-- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO 4,- CD3-117,CD3-117,CD3-117 VO -I- CD3-199,CD3-199,CD3-199 VO _e_ Plan:CO3-130,Plan:CD3-130,CD3-130wp02 VO CD3-118,CD3-118,CD3-118 VO -B- CD3-301.CD3-301,CD3-301 V4 -8- CD3-119PB1wp11 HALLIBURTON ConocoPhillips CD3- 119PB1wp11 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 16:00,December 08 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 15877.48 Results Limited By: Centre Distance: 1784.12 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1125.00 CD3-119PB1wp11 (Plan: CD3-119PB1) CB-GYRO-SS 1125.00 3718.37 CD3-119PB1wp11 (Plan: CD3-119PB1) MWD+IFR-AK-CAZ-SC 3718.37 15877.48 CD3-119PB1wp11 (Plan: CD3-119PB1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2500.00 3718.37 10-3/4" x 13-1/2" 10-3/4 . 6162.07 13476.00 7-5/8" X 9-7/8" 7-5/8 0 a 5 J T p O 0 C O G 0 0 0 0 U U U V 0 \\I V ! i -''.\,_..,,,i ,1): ,' ::: ::, ,:iXi I \ , / 60- riu ' il\j\ ���I�I) ��I�jl,�ieI�� P 1111100 . 11111 �,1� / 1 1 hp, \ \i O.4, ,I10 , \ 1 (,) ,_, _ o-Ea), -`. •OnN1h11III ililil 0l // \," 030- -41 II r.. / Li c i I � i - � �� II ilk i 0 1 I I I ; 1 I I I ; i I 1 I I 1 I I l I I I I I I I I l 1 1 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -.- CD3-107,CD3-107,CD3-107 V7 -X- CD3-121,CD3-121,CD3-121 VO $ CD3-301,CD3-301A,CD3-301A VO -e_ CD3-107,CD3-107L1,CD3-107L1 VO -0- CD3-122,CD3-122,CD3-122 VO -I- CD3-301,CD3-301APB1,CD3-301APB1 VO ( CD3-108,CD3-108,CD3-108 V14 -X- CD3-123,CD3-123,CD3-123 VO -A- CD3-301,CD3-301P61,CD3-301PB1 V1 0 CD3-109,CD3-109,CD3-109 V5 .0- CD3-124,CD3-124,CD3-124 VO -A- CD3-302,CD3-302A,CD3-302A VO r CD3 110,CD3-110,CD3-110 V12 --X- CD3-125,CD3-125,CD3-125 VO -A- CD3-316,CD3-316,CD3-316 VO CD3-111,CD3-111,CD3-111 V7 _e_ CD3-125,CD3-125PB1,CD3-125PB1 VO _e_ CD3-316,CD3-316A,CD3-316A V0 -e- CD3-111,CD3-111L1,CD3-111L1 V1 -.0- CD3-125,CD3-125PB1(surface),CD3-125PB1(surface)VO -i- CD3-316,CD3-316APB1,CD3-316AP81 VO A CD3-112,CD3 112,CD3-112 V3 -9- CD3-127,CD3-127PB1,CD3-127P81 VO -t- Plan:CD3-119,Plan:CD3-119,CD3-119wp11 VO CO3-113,CD3-113,CD3-113 V6 -e- CD3-127,Plan.CD3-127,CD3-127wp05 VO -a_ Plan:CD3-120,Plan:CD3-120,CD3-120wp08 work in progress...VO X CD3-114,CD3 114,CD3-114 V14 -X- CD3-128,CD3-128,CD3-128 VO -X- Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO 0 CO3-115,CD3-115,CD3-115 VO -A- CD3-128,CD3-128,CD3-128wp07 VO Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO A CD3-117,CD3-117,CD3-117 VO -I- CD3-199,CD3-199,CD3-199 VO -9- Plan:CD3-130,Plan:CD3-130,CD3-130wp02 VO -0- CD3-118,CD3-118,CD3-118 VO _e_ CD3-301,CD3-301,CD3-301 V4 ffJ�E` -R- CD3-119PB/wp11 1 0o o G d z° U ':F a = m N o .. 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UPDATED PER K110003ACS 11 #/ / CZ GD C.A. UPDATED PER K110003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 12.5 CD3-X99 6,003,625.99 1,528,415.38 70' 25' 09.221" 150' 54' 44.833" 1387' 661' 7.3 12.8 CD3-301 6,003,621.33 1,528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 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 0D3-305 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 0D3-111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 003-112 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 0D3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150° 54' 53.950" 1311' 972' 7.3 13.2 CD3-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 131 CD3-118 6.003.544.88 1.528.064.44 70' 25' 08.372" 150° 54' 55.086" 1301' 10ll' 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 CU3-X20 6,003,535.95 1,528,025.39 70' 25' 08.2/8" 150' 54' 56.229" 1291' 1050' /.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" 82' 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, 6,003,504.45 1,527,889.34 70' 25' 07.948" 150' 55' 00.204" 1258' 1185' 7.3 12.6 CD3-X28 6,003,500.08 1,527,870.01 70' 25' 07.902" 150' 55' 00.769" 1253' 1204' 7.3 12.6 CD3-X29 CD3-X30 CD3-X31 CD3-X32 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.) y� ALPINE MODULE:CD30 UNIT: CD ConocoPhillips 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 11 111 ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-119 Plan: CD3-119 Plan: CD3-119wp12 Standard Proposal Report permit Pack NAD 27 12 December, 2011 0 4 0 I HALLIBURTON II Sperry Drilling Services ORIGINAL Northing (5000 ft/in) IiiiiI „ „ IiiiiIiii , IiiiiIiii , Iiii , 1 „ „ IiiiiImiIiiiiIii „ IiiiiIiii , _ i - - - iii 0 a - 3 - _ a - V co O O - _ CO co — CO M — _ U - . O M - co O M - — —M CO — (/) M M 0 - - 2 p a _ CD 0 0 0 CL — c 'A IL.I. — ❑ O O M N m co O U _ 7 co o O d ❑ M.,- M ❑ N U M co mM ❑ U A . .. OM is O - U /111 pC U i R C _ .„. o M _ , U _ in° N N co y _ U ��`��t U y R N O A �..' 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N. pp o 00 o O 000 CO 00 pQ Cb pp -o 00 ! ^p Qp M '3' Oc' X 0 p0 '" p�caCo 0 4) pp in ca' io,p o N i N N 'Aria -o j M co X cto,_ X N �?1 = N co po o p —o 0 a) 0 r -0 Ti- o I M CI 0 V0 --0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 L() N 6) o co (LIVII 000£) (+)voN/(-)unnoS ZLdM611-£aa---OOLL o 0 M -o OOOOZ _ CV �/ + Nr ■ > 00061. 4 - 068 t- ®2=Ns 00081 tia Vo 41) 0 -o CO 000L L _ °) -c- 00091. 0009L _ _0 0 U) E N 1, o 000S - bo ori N O CO —0) O +' OOOt,L x CZ 0 0o CO CZ 0 0000 U O0� �` ~ 0 Oc'! c0 o 0 Off! (3) LO 0000 x > CN 00 �' Co iri t 'l 0 CL 0 06, - �0 �� O co01) 0,b 9 V' 0 r 00 ,9 0.25. -00 ) -o M 0 0 19 x V71- oO c, M 02 0 —O I T 0 O 0 O O 0 O 0 O 0 O Lf) O U) O co (url1 009L) u1dea Ia3i1Jan co r� anal 1 \ 1V11i" L. ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 t Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) - Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119 Design: CD3-119wp12 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°58'43.6520274 N From: Map Easting: -401.28ft Longitude: 152°19'30.2312389 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-119 Well Position +N/-S 0.00 ft Northing: 6,003,792.97ft Latitude: 70°25'9.4879268 N +E/-W 0.00 ft Easting: 388,012.95 ft Longitude: 150°54'44.2823715 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft Wellbore Plan:CD3-119 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 12/9/2011 15.89 79.82 57,343 Design CD3-119wp12 Audit Notes: Version: Phase: PLAN Tie On Depth: 13,476.00 Vertical Section: Depth From(TVD) +N/S +E/-W Direction, . (ft) (ft) (ft) (°) 36.30 0.00 0.00 325.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 13,476.00 68.08 358.45 6,162.07 6,112.97 9,912.08 5,126.50 0.00 0.00 0.00 0.00 13,563.65 67.79 355.16 6,195.00 6,145.90 9,993.17 5,121.98 3.50 -0.33 -3.76 -96.00 14,356.64 65.52 338.05 6,511.18 6,462.08 10,698.15 4,955.03 2.00 -0.29 -2.16 -101.57 14,375.20 65.52 338.05 6,518.87 6,469.77 10,713.81 4,948.71 0.00 0.00 0.00 0.00 15,481.08 83.00 323.90 6,819.10 6,770.00 11,635.46 4,430.75 2.00 1.58 -1.28 -40.13 15,501.08 83.00 323.90 6,821.54 6,772.44 11,651.50 4,419.05 0.00 0.00 0.00 0.00 15,820.93 89.40 323.90 6,842.73 6,793.63 11,909.23 4,231.10 2.00 2.00 0.00 0.05 21,177.64 89.40 323.90 6,899.10 6,850.00 16,237.19 1,075.19 0.00 0.00 0.00 0.00 12/12/2011 3:56:48PM P1 r,age 2 COMPASS 2003.16 Build 69 ARR ;� l ki i\ ......i R a``ti a u u, ConocoPhillips HALLI B U RTO N Standard Proposal Report ms Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 .,µ. Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119 Design: CD3-119wp12 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/$ +EI-W Northing Easting DLS Vert Section (ft) C) C) (ft) ft (ft) (ft) (ft) (ft) 6,112.97 13,476.00 68.08 358.45 6,162.07 6,112.97 9,912.08 5,126.50 6,013,626.19 393,287.12 3.50 5,179.06 KOP:DLS 3.50 TFO-96.00-7-5/8"X 9-7/8" 13,500.00 67.99 357.55 6,171.04 6,121.94 9,934.33 5,125.73 6,013,648.44 393,286.68 3.50 5,197.73 13,563.65 67.79 355.16 6,195.00 6,145.90 9,993.17 5,121.98 6,013,707.32 393,283.82 3.50 5,248.08 Start DLS 2.00 TFO-101.19 13,574.48 67.75 354.93 6,199.10 6,150.00 10,003.16 5,121.11 6,013,717.33 393,283.10 2.00 5,256.76 ShaleAboveHRZ 13,600.00 67.65 354.39 6,208.78 6,159.68 10,026.67 5,118.92 6,013,740.86 393,281.25 2.00 5,277.28 13,700.00 67.27 352.26 6,247.12 6,198.02 10,118.39 5,108.18 6,013,832.73 393,271.90 2.00 5,358.57 13,800.00 66.92 350.12 6,286.05 6,236.95 10,209.42 5,094.08 6,013,923.95 393,259.16 2.00 5,441.22 13,900.00 66.60 347.97 6,325.51 6,276.41 10,299.62 5,076.62 6,014,014.40 393,243.06 2.00 5,525.13 14,000.00 66.31 345.82 6,365.46 6,316.36 10,388.90 5,055.84 6,014,103.97 393,223.62 2.00 5,610.18 14,100.00 66.05 343.65 6,405.85 6,356.75 10,477.15 5,031.75 6,014,192.56 393,200.87 2.00 5,696.28 14,200.00 65.82 341.47 6,446.63 6,397.53 10,564.25 5,004.39 6,014,280.06 393,174.82 2.00 5,783.33 14,206.02 65.81 341.34 6,449.10 6,400.00 10,569.46 5,002.64 6,014,285.29 393,173.14 2.00 5,788.60 ShaleAboveHRZBase 14,300.00 65.62 339.29 6,487.76 6,438.66 10,650.11 4,973.79 6,014,366.36 393,145.50 2.00 5,871.21 14,303.26 65.61 339.22 6,489.10 6,440.00 10,652.88 4,972.74 6,014,369.15 393,144.50 2.00 5,874.09 Top HRZ 14,356.64 65.52 338.05 6,511.18 6,462.08 10,698.15 4,955.03 6,014,414.67 393,127.47 2.00 5,921.32 14,364.92 65.52 338.05 6,514.61 6,465.51 10,705.13 4,952.21 6,014,421.69 393,124.76 0.00 5,928.66 Start 19.87 hold at 14364.92 MD 14,375.20 65.52 338.05 6,518.87 6,469.77 10,713.81 4,948.71 6,014,430.42 393,121.39 0.00 5,937.77 14,384.79 65.67 337.91 6,522.83 6,473.73 10,721.91 4,945.44 6,014,438.57 393,118.24 2.00 5,946.28 Start DLS 2.00 TFO-39.87 14,400.00 65.90 337.70 6,529.07 6,479.97 10,734.75 4,940.20 6,014,451.49 393,113.19 2.00 5,959.81 14,500.00 67.44 336.31 6,568.67 6,519.57 10,819.27 4,904.32 6,014,536.53 393,078.59 2.00 6,049.62 14,600.00 68.99 334.95 6,605.78 6,556.68 10,903.85 4,866.00 6,014,621.66 393,041.54 2.00 6,140.89 14,700.00 70.55 333.61 6,640.36 6,591.26 10,988.37 4,825.27 6,014,706.78 393,002.10 2.00 6,233.49 14,711.27 70.73 333.46 6,644.10 6,595.00 10,997.90 4,820.53 6,014,716.37 392,997.50 2.00 6,244.00 Base HRZ 14,800.00 72.12 332.31 6,672.36 6,623.26 11,072.75 4,782.20 6,014,791.79 392,960.30 2.00 6,327.31 14,832.16 72.63 331.89 6,682.10 6,633.00 11,099.84 4,767.86 6,014,819.08 392,946.36 2.00 6,357.72 K-1 14,900.00 73.70 331.02 6,701.75 6,652.65 11,156.88 4,736.83 6,014,876.58 392,916.20 2.00 6,422.24 14,944.97 74.41 330.45 6,714.10 6,665.00 11,194.60 4,715.70 6,014,914.61 392,895.63 2.00 6,465.26 Top Kuparuk D 15,000.00 75.29 329.76 6,728.48 6,679.38 11,240.65 4,689.22 6,014,961.05 392,869.85 2.00 6,518.17 15,085.01 76.64 328.70 6,749.10 6,700.00 11,311.51 4,647.02 6,015,032.52 392,828.73 2.00 6,600.42 Top Kuparuk C 15,100.00 76.88 328.51 6,752.53 6,703.43 11,323.96 4,639.42 6,015,045.09 392,821.32 2.00 6,614.98 15,106.93 76.99 328.43 6,754.10 6,705.00 11,329.72 4,635.89 6,015,050.90 392,817.87 2.00 6,621.72 LCU 15,200.00 78.48 327.28 6,773.87 6,724.77 11,406.71 4,587.50 6,015,128.61 392,770.65 2.00 6,712.55 15,300.00 80.08 326.07 6,792.47 6,743.37 11,488.81 4,533.52 6,015,211.49 392,717.91 2.00 6,810.76 12/12/2011 3.56:48PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119 Design: CD3-119wp12 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) 6,750.00 15,339.79 80.72 325.59 6,799.10 6,750.00 11,521.27 4,511.49 6,015,244.28 392,696.36 2.00 6,849.99 Base Nuiqsut 15,400.00 81.69 324.86 6,808.30 6,759.20 11,570.14 4,477.55 6,015,293.65 392,663.17 2.00 6,909.49 15,441.82 82.37 324.36 6,814.10 6,765.00 11,603.90 4,453.57 6,015,327.77 392,639.70 2.00 6,950.90 Top Nechelik 15,481.08 83.00 323.90 6,819.10 6,770.00 11,635.46 4,430.75 6,015,359.66 392,617.36 2.00 6,989.84 CD3-198A 09Dec11 Heel 15,481.69 83.00 323.90 6,819.17 6,770.07 11,635.95 4,430.39 6,015,360.15 392,617.01 0.00 6,990.44 Start 20.00 hold at 15481.69 MD-7-5/8"X 9-7/8" 15,500.00 83.00 323.90 6,821.41 6,772.31 11,650.63 4,419.69 6,015,374.99 392,606.52 0.00 7,008.61 15,501.08 83.00 323.90 6,821.54 6,772.44 11,651.50 4,419.05 6,015,375.87 392,605.90 0.00 7,009.68 15,501.69 83.01 323.90 6,821.61 6,772.51 11,651.99 4,418.70 6,015,376.36 392,605.56 2.00 7,010.29 Start DLS 2.00 TFO 0.00 15,600.00 84.98 323.90 6,831.90 6,782.80 11,730.98 4,361.09 6,015,456.20 392,549.14 2.00 7,108.04 15,700.00 86.98 323.90 6,838.91 6,789.81 11,811.57 4,302.31 6,015,537.66 392,491.59 2.00 7,207.77 15,800.00 88.98 323.90 6,842.44 6,793.34 11,892.32 4,243.43 6,015,619.27 392,433.93 2.00 7,307.68 15,820.93 89.40 323.90 6,842.73 6,793.63 11,909.23 4,231.10 6,015,636.37 392,421.85 2.00 7,328.61 15,821.54 89.40 323.90 6,842.74 6,793.64 11,909.72 4,230.74 6,015,636.86 392,421.50 0.00 7,329.22 Start 5356.65 hold at 15821.54 MD 15,900.00 89.40 323.90 6,843.56 6,794.46 11,973.11 4,184.52 6,015,700.94 392,376.24 0.00 7,407.66 16,000.00 89.40 323.90 6,844.62 6,795.52 12,053.91 4,125.60 6,015,782.60 392,318.55 0.00 7,507.63 16,100.00 89.40 323.90 6,845.67 6,796.57 12,134.70 4,066.69 6,015,864.26 392,260.86 0.00 7,607.61 16,200.00 89.40 323.90 6,846.72 6,797.62 12,215.50 4,007.77 6,015,945.93 392,203.17 0.00 7,707.58 16,300.00 89.40 323.90 6,847.77 6,798.67 12,296.29 3,948.86 6,016,027.59 392,145.47 0.00 7,807.56 16,400.00 89.40 323.90 6,848.83 6,799.73 12,377.09 3,889.94 6,016,109.25 392,087.78 0.00 7,907.54 16,500.00 89.40 323.90 6,849.88 6,800.78 12,457.88 3,831.03 6,016,190.91 392,030.09 0.00 8,007.51 16,600.00 89.40 323.90 6,850.93 6,801.83 12,538.68 3,772.11 6,016,272.58 391,972.40 0.00 8,107.49 16,700.00 89.40 323.90 6,851.98 6,802.88 12,619.47 3,713.20 6,016,354.24 391,914.71 0.00 8,207.47 16,800.00 89.40 323.90 6,853.04 6,803.94 12,700.27 3,654.28 6,016,435.90 391,857.02 0.00 8,307.44 16,900.00 89.40 323.90 6,854.09 6,804.99 12,781.06 3,595.37 6,016,517.57 391,799.32 0.00 8,407.42 17,000.00 89.40 323.90 6,855.14 6,806.04 12,861.86 3,536.45 6,016,599.23 391,741.63 0.00 8,507.39 17,100.00 89.40 323.90 6,856.19 6,807.09 12,942.65 3,477.54 6,016,680.89 391,683.94 0.00 8,607.37 17,200.00 89.40 323.90 6,857.24 6,808.14 13,023.45 3,418.62 6,016,762.56 391,626.25 0.00 8,707.35 17,300.00 89.40 323.90 6,858.30 6,809.20 13,104.25 3,359.71 6,016,844.22 391,568.56 0.00 8,807.32 17,400.00 89.40 323.90 6,859.35 6,810.25 13,185.04 3,300.79 6,016,925.88 391,510.87 0.00 8,907.30 17,500.00 89.40 323.90 6,860.40 6,811.30 13,265.84 3,241.88 6,017,007.54 391,453.17 0.00 9,007.27 17,600.00 89.40 323.90 6,861.45 6,812.35 13,346.63 3,182.96 6,017,089.21 391,395.48 0.00 9,107.25 17,700.00 89.40 323.90 6,862.51 6,813.41 13,427.43 3,124.04 6,017,170.87 391,337.79 0.00 9,207.23 17,800.00 89.40 323.90 6,863.56 6,814.46 13,508.22 3,065.13 6,017,252.53 391,280.10 0.00 9,307.20 17,900.00 89.40 323.90 6,864.61 6,815.51 13,589.02 3,006.21 6,017,334.20 391,222.41 0.00 9,407.18 18,000.00 89.40 323.90 6,865.66 6,816.56 13,669.81 2,947.30 6,017,415.86 391,164.72 0.00 9,507.15 18,100.00 89.40 323.90 6,866.71 6,817.61 13,750.61 2,888.38 6,017,497.52 391,107.02 0.00 9,607.13 18,200.00 89.40 323.90 6,867.77 6,818.67 13,831.40 2,829.47 6,017,579.19 391,049.33 0.00 9,707.11 18,300.00 89.40 323.90 6,868.82 6,819.72 13,912.20 2,770.55 6,017,660.85 390,991.64 0.00 9,807.08 18,400.00 89.40 323.90 6,869.87 6,820.77 13,992.99 2,711.64 6,017,742.51 390,933.95 0.00 9,907.06 12/12/2011 3:56:48PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119 Design: CD3-119wp12 Planned Survey Measured Vertical Map Map 1 Depth Inclination Azimuth Depth TVDss +N/S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,821.82 18,500.00 89.40 323.90 6,870.92 6,821.82 14,073.79 2,652.72 6,017,824.18 390,876.26 0.00 10,007.03 18,600.00 89.40 323.90 6,871.98 6,822.88 14,154.58 2,593.81 6,017,905.84 390,818.57 0.00 10,107.01 18,700.00 89.40 323.90 6,873.03 6,823.93 14,235.38 2,534.89 6,017,987.50 390,760.87 0.00 10,206.99 18,800.00 89.40 323.90 6,874.08 6,824.98 14,316.18 2,475.98 6,018,069.16 390,703.18 0.00 10,306.96 18,900.00 89.40 323.90 6,875.13 6,826.03 14,396.97 2,417.06 6,018,150.83 390,645.49 0.00 10,406.94 19,000.00 89.40 323.90 6,876.19 6,827.09 14,477.77 2,358.15 6,018,232.49 390,587.80 0.00 10,506.91 19,100.00 89.40 323.90 6,877.24 6,828.14 14,558.56 2,299.23 6,018,314.15 390,530.11 0.00 10,606.89 19,200.00 89.40 323.90 6,878.29 6,829.19 14,639.36 2,240.32 6,018,395.82 390,472.42 0.00 10,706.87 19,300.00 89.40 323.90 6,879.34 6,830.24 14,720.15 2,181.40 6,018,477.48 390,414.72 0.00 10,806.84 19,400.00 89.40 323.90 6,880.39 6,831.29 14,800.95 2,122.48 6,018,559.14 390,357.03 0.00 10,906.82 19,500.00 89.40 323.90 6,881.45 6,832.35 14,881.74 2,063.57 6,018,640.81 390,299.34 0.00 11,006.79 19,600.00 89.40 323.90 6,882.50 6,833.40 14,962.54 2,004.65 6,018,722.47 390,241.65 0.00 11,106.77 19,700.00 89.40 323.90 6,883.55 6,834.45 15,043.33 1,945.74 6,018,804.13 390,183.96 0.00 11,206.75 19,800.00 89.40 323.90 6,884.60 6,835.50 15,124.13 1,886.82 6,018,885.79 390,126.27 0.00 11,306.72 19,900.00 89.40 323.90 6,885.66 6,836.56 15,204.92 1,827.91 6,018,967.46 390,068.57 0.00 11,406.70 20,000.00 89.40 323.90 6,886.71 6,837.61 15,285.72 1,768.99 6,019,049.12 390,010.88 0.00 11,506.68 20,100.00 89.40 323.90 6,887.76 6,838.66 15,366.51 1,710.08 6,019,130.78 389,953.19 0.00 11,606.65 20,200.00 89.40 323.90 6,888.81 6,839.71 15,447.31 1,651.16 6,019,212.45 389,895.50 0.00 11,706.63 20,300.00 89.40 323.90 6,889.86 6,840.76 15,528.11 1,592.25 6,019,294.11 389,837.81 0.00 11,806.60 20,400.00 89.40 323.90 6,890.92 6,841.82 15,608.90 1,533.33 6,019,375.77 389,780.12 0.00 11,906.58 20,500.00 89.40 323.90 6,891.97 6,842.87 15,689.70 1,474.42 6,019,457.44 389,722.42 0.00 12,006.56 20,600.00 89.40 323.90 6,893.02 6,843.92 15,770.49 1,415.50 6,019,539.10 389,664.73 0.00 12,106.53 20,700.00 89.40 323.90 6,894.07 6,844.97 15,851.29 1,356.59 6,019,620.76 389,607.04 0.00 12,206.51 20,800.00 89.40 323.90 6,895.13 6,846.03 15,932.08 1,297.67 6,019,702.43 389,549.35 0.00 12,306.48 20,900.00 89.40 323.90 6,896.18 6,847.08 16,012.88 1,238.76 6,019,784.09 389,491.66 0.00 12,406.46 21,000.00 89.40 323.90 6,897.23 6,848.13 16,093.67 1,179.84 6,019,865.75 389,433.97 0.00 12,506.44 21,100.00 89.40 323.90 6,898.28 6,849.18 16,174.47 1,120.93 6,019,947.41 389,376.28 0.00 12,606.41 21,177.64 89.40 323.90 6,899.10 6,850.00 16,237.19 1,075.19 6,020,010.81 389,331.49 0.00 12,684.03 CD3-198A 09Dec11 Toe Targets it Target Name hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) CD3-198A 09Dec11 Heel 0.00 0.00 6,819.10 11,635.46 4,430.75 6,015,359.66 392,617.36 -plan hits target center -Circle(radius 100.00) CD3-198A 09Dec11 Toe 0.00 0.00 6,899.10 16,237.19 1,075.19 6,020,010.81 389,331.49 -plan hits target center -Circle(radius 100.00) 12/12/2011 3.56:48PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-119 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-119 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-119 Design: CD3-119wp12 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,718.37 2,500.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 13,476.00 6,162.07 7-5/8"X 9-7/8" 7-5/8 9-7/8 15,481.69 6,819.17 7-5/8"X 9-7/8" 7-5/8 9-7/8 21,178.19 6,899.11 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 15,339.79 6,799.10 Base Nuiqsut 15,441.82 6,814.10 Top Nechelik 15,106.93 6,754.10 LCU 14,303.26 6,489.10 Top HRZ 14,944.97 6,714.10 Top Kuparuk D 14,206.02 6,449.10 ShaleAboveHRZBase 14,832.16 6,682.10 K-1 13,023.88 5,989.10 Albian 96 13,574.48 6,199.10 ShaleAboveHRZ 14,711.27 6,644.10 Base HRZ 15,085.01 6,749.10 Top Kuparuk C Plan Annotations <,>v,._,., r; ..4e e -.*w¢•:,f >•>A. ,4:'''"-'7' , :., s,.: ,. -n. ..r.vm . , >-. .r.,..‘'..".•,..".."-''-'"'"''''-` x,''r:. ,•.ri,,. Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment t':; -a 13,476.00 6,162.07 9,912.08 5,126.50 KOP: DLS 3.50 TFO-96.00 13,563.65 6,195.00 9,993.17 5,121.98 Start DLS 2.00 TFO-101.19 14,364.92 6,514.61 10,705.13 4,952.21 Start 19.87 hold at 14364.92 MD 14,384.79 6,522.83 10,721.91 4,945.44 Start DLS 2.00 TFO-39.87 15,481.69 6,819.17 11,635.95 4,430.40 Start 20.00 hold at 15481.69 MD I 15,501.69 6,821.61 11,651.99 4,418.70 Start DLS 2.00 TFO 0.00 15,821.54 6,842.74 11,909.72 4,230.74 Start 5356.65 hold at 15821.54 MD 21,178.19 TD at 21178.19 I 1 12/12/2011 3:56.48PM Page 6 COMPASS 2003.16 Build 69 ZI, ID o ° a `" Q m ra P = N CO a Zn c aq Y U •I - N en N V .° en °' ✓• to C W 4 O. 02O ` 7 to _ O d eh 0 W 0 0 p O ce V r A .C ' Z 2 O r•. Z N d + k e )M J ONC1/4. co O Qto• F. O i • �fd L `T � f� a) w C 'C s'-' n /A •_ /W ` M a0 T j , O /N�/ p �o N o 3 zc c IVa00 . 0 ■� • = o a $ u w a) 'Y4 ♦^ C C 03• in C J v • a. —1111111.1111 Q 4 a- z• co •m a ▪ /off tao _O r _C N r• 7 U W /^ �_ O r N W w �/, r X L 'N M p =.. Q I— CL N O o r) m p0, n .aE O ti g T N a 00 o Q O Q T rsz. ., L r . 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CID en p 3 °' U - M eo p a U - 3 Li1 - per, c� p p U Miwr p U 6i U U U c,-) Nb A • p U N U — Q @ _ o M CO M M M p M ♦eb i ‘ u M CD r ` � M p U / �'I11 0 — U 0 o 1 N - C_ a C M CO - -0 M �� p N 0 0 0 - • M CO c en C p N M N r. IV U p Ad ., V' W U co ,1��W U M to COCO 0 CL Adit U .1. 1 N U _ ch IP M — 16.4 A - 0!) 1 p ililli M !A U Z p 6.4 Z� p Yyd _ U t O.� R 1: 'a - to)vi '4. Z _ CU R ado _ �� = ate _ VZ 0 - �Cv o = 0 ihio I I I I I I I I I I I I I 1 1 1 1 1 1 ! I I I I I l l I I I T I 1 I I i l l l I 1 1 1 1 ! I l I I l I l I I l I I l l l I 1 1 1 1 ! (1-1!/4 000P) 6t1441-10N ORIGINAL U' Q, CO 3 o c a. ,� 0 C.; co 0 _c Y Y Y Y Y 11 V) N U) N N et �. O a' Cr d' 62 62 � C-C ` O O O O O R N (6 (0 (0 @ fl_ 2 2 2 2 2 U d . (r) N N N 0 N N CO) a d a a a co .. c .0 .°a t. d O O O 2 O a) O N £ -8 -8 -508. 0 R 7 R c p m E I1 (L LL LL as <9 t", •c U o U) u a) `2 in U U U U 0 R C C C C C V) V) V) V) U E a) m as R m a)• o N N N N E a) a) a) CU a) c ~ Q 0 Q Q Cl) 0 0 0 0 0 0 0 (n Y Y Y Y u) O N M N N u? QN Q Q Q O N CO O) M (7 u) O O LL R Q' R' C ,- W (O e- N CO N a LL LL LL LL o V M r- OO O ( d LL L11 0 0 0 0 0 U 02222 0 0 0 0 0 0 o y 0 0 CD 0 0 0 2 L N O V O O O CO V O) 0 (() O c Q=r V ,— N I!7 (O c0 y a) O Lri V M p2 p V LO CO C O CO LO V N (O CO d ° CO co. r C (O C. R E (MO (00 CO CV CV O O ._ R v c- W y N 'O p lt p CO CD ` U coOV O cocooC N L M O N (h O V O co 0 r (O O co to N c (ha °- v_ co r- to (o N E. 1.. w m 0 v v v ri v -5.. a a O 7 a) A d1 N O V N W C') (a R E Ncsi 4- O u) O V N O- . N E A = co co v v a) M o 3 °' .E ` U) 0 c c o .9- - a co UW _ N N_ • N co O) O N C O I0 co co V O 00 d 4 U U) .0 L o NA o 4 (0 3 3o = a) CO .0 ' E 7 co r� co O M co0) O) N O N V co r N CD N- aa, Rp v v v h v U39 a)rZ " 00 uS a) ico s U U c c 3M R U na o m U 0 CZ j d ti•0 3 0 0 0 C .. o Lo p ui co (D ao d) A E C N Q�1 -O N a. N N O =+ N r V V N- CO r Vi U C_ ` U o O) O O ~ M O N ^ = O O CL .- a 0 o U) 3 3 N T m N A 0 0 U) a s U) U 0 aRi o E _ 0 () () N = o a) CD ll Z U 1 3 2 N C - C O C R m M M (O N C — Ov) 1F O a v d 0 0 0 i 0 0 r- O O) N U) N U a` �.+ 0 U U co 0 CO o (o N a) o O L u _a o oM m i0 E M ClN W U N N N O y a R (h O) 0 0 0 4t -r� v v m j 9 N OO 7 3 M M o ,_ — LL M "O (n U) CV a 6 _^U M U (h M M O « O U U In Q�re E O N • d V 0 ' 0 0 0 O Us c CO a) U V CC X LL O .� E . 0E000 •" N o N rn U a) O` M O T R J a C C C O Q a N C a) e- 0 o Z r` m COCO U o °) 17.;�° 3 M = s U (c d R M a a a .� N u o W O M M co co Q) O O O n 6 U II N N O N 0 0 0 u! c C U) t_ •N Z .y U) O 0 to 0 0 0 E O_ N O -O a .J __ y d N E H 0 (h M M « •— y a7 O E cu J O "CI 0 a).� R a LL o 0 0 0 o o c a) LL 4 o m0 U d CC CC « O M COD c c c o o c c O R R R N N (4 C O O V U U U d d a Q 0 Q C N 12 N O Q F !f7 fn w U (n D U Q 1rdGLNAL HALLIBURTON ConocoPhillips CD3-119wp12 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 14:48,December 09 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 13476.00 To 21178.19 Results Limited By: Centre Distance: 2314.19 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1125.00 CD3-119PB1wp11 (Plan: CD3-119PB1) CB-GYRO-SS 1125.00 3718.37 CD3-119PB1wp11 (Plan: CD3-119PB1) MWD+IFR-AK-CAZ-SC 3718.37 13476.00 CD3-119PB1wp11 (Plan: CD3-119PB1) MWD+IFR-AK-CAZ-SC 13476.00 15481.69 CD3-119wp12 (Plan: CD3-119) MWD+IFR-AK-CAZ-SC 15481.69 21178.02 CD3-119wp12 (Plan: CD3-119) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2500.00 3718.37 10-3/4" x 13-1/2" 10-3/4 6162.07 13476.00 7-5/8" X 9-7/8" 7-5/8 6819.10 15481.69 7-5/8" X 9-7/8" 7-5/8 6899.10 21178.19 4-1/2"x 6-3/4" 4-1/2 . E 0 v _ / NJ C n a> - 112 - / ) CI) _ U 30 / N c CD U - 0 I 1 I I I I I I I I I I I I 1 1 I I I I I I 1 1 1 I I 1 13500 14250 15000 15750 16500 17250 18000 18750 Measured Depth LEGEND -e- CD3-107,CD3-107,CD3-107 V7 -ger- CD3-121,CD3-121,CD3-121 VO -8- CD3-301,CD3-301A,CD3-301A VO O CD3 107,CD3-107L1,CD3-107L1 VO _e_ CD3-122,CD3-122,CD3-122 VO - -- CD3-301,CD3-301APB1,CD3-301APB1 VO Q CD3-108,CD3-108,CD3-108 V14 --0- CD3-123,CD3-123,CD3-123 VO -X- CD3-301,CD3-301PB1,CD3-301PB1 V1 CD3 109,CD3 109,CD3-109 V5 0 CO3-124,CD3-124,CD3-124 VO -XF CD3-302,CD3-302A,CD3-302A VO -A- CD3-110,CD3-110,CD3-110 V12 -0- CO3-125,CD3-125,CD3-125 VO -X- CD3-316,CD3-316,CD3-316 VO CD3-111,CD3-111,CD3-111 V7 -0- CD3-125,CD3-125PB1,CD3-125PB1 VO -4-- CD3-316,CD3-316A,CD3-316A VO -9- CD3-111,CD3-111L1,CD3-111L1 V1 -e_ CO3-125,CD3-125PB1(surface),CD3-125PB1(surface)VO --- CD3-316,CD3-316APB1,CD3-316APB1 VO X CD3 112,CD3-112,CD3-112 V3 --i-'- CD3-127,CD3-127PB1,CD3-127PB1 VO -Ar- Plan:CD3-119,Plan:CD3-119PB1,CD3-119PB1wp11 VO CD3-113,CD3-113,CO3-113 V6 _e_ CD3-127,Plan:CD3-127,CD3-127wp05 VO --I- Plan:CD3-120,Plan:CD3-120,CD3-120wp08 work in progress...VO -0- CD3-114,CD3-114,CD3-114 V14 -0- CD3-128,CD3-128,CD3-128 VO $- Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO $- CD3-115,CD3-115,CD3-115 VO -X- CD3-128,CD3-128,CD3-12Bwp07 VO -A- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO CD3-117,CD3-117,CD3-117 VO 41- CD3-199,CD3-199,CD3-199 VO $ Plan.CD3-130,Plan,CD3-130,CD3-130wp02 VO CD3-118,CD3-118,CD3-118 VO -I- CD3-301,CD3-301,CD3-301 V4 -B- CD3-119wp12 0 i . F , E a . 616.... 88. 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UPDATED PER K110003ACS 11 effAff CZ GD C.A. UPDATED PER K110003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3-X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150' 54' 44.278" 392' 642' 7.3 2.5 CD3-X99 6,003,625.99 1,528,415.38 70' 25' 09.221" 150' 54' 44.833" 387' 661' 7.3 2.8 003-301 6,003,621.33 1,528,395.58 70' 25' 09.172" 150' 54' 45.411" 382' 680' 7.3 3.5 003-302 6,003,616.72 1,528,376.38 70' 25' 09.124" 150' 54' 45.972" 377' 700' 7.3 3.2 003-303 6,003,612.52 1,528,356.72 70' 25' 09.080" 150' 54' 46.547" 373' 719' 7.3 3.3 CD3-304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150' 54' 47.122" 368' 739' 7.3 3.4 003-305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150' 54' 47.691" 363' 758' 7.3 3.6 003-106 6,003,599.43 1,528,298.37 70' 25' 08.942" 150' 54' 48.252" 359' 777' 7.3 3.4 CD3-107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150' 54' 48.820" 354' 797' 7.3 3.2 003-108 6,003,589.85 1,528,259.61 70' 25' 08.842" 150° 54' 49.385" 349' 816' 7.3 3.1 003-109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962" 344' 836' 7.3 3.1 003-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54' 50.533" 339' 855' 7.3 3.0 003-111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150' 54' 51.095" 334' 874' 7.3 2.9 003-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54' 51.676" 330' 894' 7.3 3.1 003-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54' 52.255" 325' 914' 7.3 3.1 003-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150' 54' 52.815" 320' 933' 7.3 3.3 003-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150° 54' 53.388" 315' 953' 7.3 3.2 0D3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150° 54' 53.950" 311' 972' , 7.3 3.2 003-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 306' 991' 7.3 31 CD3-118 6.003.544.88 1.528.064.44 70' 25' 08.372" 150' 54' 55.086" 301' 011' 7.3 2.8 CD3-X19 6,003,540.17 1,528,044.86 70' 25' 08.322" 150' 54' 55.660" 296' 030' 7.3 2.8 CL),5-X2U 6,003,535.95 1,528,025.39 70' 25' 08.278" 150' 54 56.229" 291' 050' /•5 2.6 CD3-X21 6,003,531.41 1,528,006.04 70' 25' 08.230" 150' 54' 56.794" 286' 069' 7.3 2.5 003-122 6,003,527.00 1,527,986.67 70' 25' 08.184" 150' 54' 57.360" 282' 088' 7.3 2.6 0D3-X23 6,003,522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 277' 108' 7.3 2.6 003-124 6,003,518.17 1,527,947.59 70' 25' 08.091" 150' 54' 58.502" 272' 127' 7.3 2.5 0D3-X25 6,003,513.62 1,527,927.89 70' 25' 08.044" 150' 54' 59.078" 267' 147' 7.3 2.6 0D3-X26 6,003,508.97 1,527,908.70 70' 25' 07.995" 150° 54' 59.639" 263' 166' 7.3 2.6 CD3-X27 6,003,504.45 1,527,889.34 70' 25' 07.948" 150' 55' 00.204" 258' 185' 7.3 2.6 CD3-X28 6,003,500.08 1,527,870.01 70' 25' 07.902" 150' 55' 00.769" 253' 204' 7.3 2.6 CD3-X29 CD3-X30 CD3-X31 CD3-X32 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.) `"' ALPINE MODULE:0D30 UNIT: CD ConocoPhillips 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-CD3 0-111 2 OF 3 11 III El y o) p a) a , p N a I co vii: , : , o F. a j. O J N, w O. a. Q, o) 3 0 o c d: 3 0) 3. co r, �' c �, CO, 3: �: S v a) as: �: 0 a), w CO N O O o: 0 c: -o ly4' a y' C c v: j a •- Q: ) �: •0: �, c, , v: 3,' la o) 'c 2: c, c 0) m: m, 3' >, y: c > �, __: CA)__ �, a 0) 3 2, a) o 4, p' N a) a)' m' Y co a ,- w, a U • o 0 p, 3' N C, p; • -0 a N, , a0, co O a, C 2 — N c y C: 2 r O ...r M. N a a3 0) co, O' i, C U) (a C p o) ?�, : 0' a y, y O M J V' L: CO', 3el y, 'Cl. v. QZp n, a Ot CO. m • N, �,• Q OY o) O, �: U 'd N' ui ' N, Q�, m' �, a), L �, Q: CO 0 CO, W M. LQ IfLc= ) M: N a 0, c, .0. 0' II: 0 �, O o a , .< Z LLZ, Z Z:to, 2: C: C: a) a ' Z v O, p: E: Y y: y: a o, z 0 0 > O, O: O: : ., -7 �: 3 _., 1i a 0. •o, 0, v Z o' a LI: 2, g: g: F,: , Cr o: E: 0. R: y: X: co, c, E: a)o ZI °' Z Z o: o< O: o, o' o V: 0 �: w o: >: o: • Q: o, o, y w 0) o, 0 0 0: 0: y: , Z a O �' d o, 2: g: z' CO o > , , , , I 2 0, O Q Q 0 N, CO a), 0,, a). a) a),N, aa)i, 0,, a 0): N, Q, Q, Q, N, < CO 0 a ay), N, Q N, Q, N aa),: a, aa)i, a y), O, < a), N, Q: Q. Q, p. Z, Z, >: }: >- }, }, >- >: >: >, >, >-: }: z, z, Z, ,>, Z, >, Z >-; >, >: Z >: Z >, >-: >, >- >- Z Z ;}: >- Z, Z Z , , , o a) co to U y: o , C: a-. � a), To - , , E a) o, 0 O .> 0 o O , , O, . O _ , c s o a E 0 k O 0 N, U N o 3. M , y a.), Z I O c aci Z: o' ti O: 2 ate. avi: E a), 2 LL:. �: a), 0"N ". N: C,, a O. 7: c E a y a) a N c O E' N N �-i- w M: 3: " cp, > a)' .a: a)• o y v, y: ° c o, N n 2: 3: D o: O: c. .0 , 3' 9: V 4 • p: $ O. G O w, O: co o IL z CC 0 0: '0' �O' c N: p, E '0 a). a), 4 D O: `: y, m: p: o: p) L: : C y: p �, J — M: c c .y H C' O N: Ot o d" C, O L' 0. a N L 0: c C E, E 'C, v: c, c, E, N O J Q m: o 0 9 7 O v `6 c 3 O U " (0 V c O O a) y y) ). _ c 0 v: m d: y o o p m j n a 4 a) ._ o yj d a' 3. > as Y a) y J Q o a _° �' d S o > > °' a ns; a Y m• � ° o °' o• g E m m m Q m v) >. o m a m' - y: d, a c, c c: 4 w w_, E 3 m o E yi U Q c o, 2, a a) 0 o, . w a m 0 v 0, as L: c, °: N, co, to y: -c cm c y o a 3 0 c' o >, 3 c E TD m O, .E c 2 y y m: a o ( 3, 3 ami 0 a) .., 32, y' •'(: .°7.- 3: 2: o o a o N 4 �' 0 03, 0 3 0 �, o W U o a w a v C f0' N' v' > •> U' O v' y o' a s O c: p. c. w: '�. °D: >: o' a) p; 'O, '0 0: cc E, d p' a) O: o: c: o- �O y: -0: N: a): o O) c. "o a y, > a) a_ =r1 8 6' a a). D' m CD' ao) a g .- 0, ; a c, a v a a 0) w x, D a) o, m m' E' 0) o :~' m' o D c 0' y o cO L' a a), a a a tlD y a t, a N' d a) 01 m: •..: 'a, c: U: 3' N, :3, co O' yj c t o = �, v. a). E. o o. m 3' CO, m CO, y v : c, 0) 0: M: m. y vi D a .o 2 c. .N •.�, o: n To 0- a B. �, C. C a a d vi > N a)' a) a) 3 c .p '-c' c 0. 0, y c. a7 a �, w 7: o' U.. a) h � N ii as a _ a v. v a m a, a a v a) yr '-' ). D >o' ami c .c 3 v c' c) -0 c m c' E 0 c, a)' E. y w a), a a): .{ O L, c, c ."• as .ti 3 7' a) CO' O. O a) _ 0, N a) o p, m c a). c, O a) O > w C. 3 m t: a) m m o 0 m ; a c) c,,), a� o, o, ' V m v` m, D. vi E .3 c •o U' a) y, v, N Z c: c v v 3 C v y o a) c• v O p a) 6 o o' o .- .- o "' E. .E p a) n -p' as I- I- I-! 'v o' 3 > a a; Y' - o' c (E w y; a U o a`) a, "c a) d D, 4 4 a), a`) m, m 3 2 0 a, M, M, M, m -o m, V. `a, = 0 0, -o O a 0 a), a) a), a) o 0 V_ Z. d, J, D, moi': s, tn, w O, O. d, 0_, U, � Q, c_ U U), U, O. 0, U Q Q r-, o m m, 0, y', M d, 0, co, co U U4 a r N M V u) O W 0) O N M v )n (O h CA 0) O N M V u) O h ao 0) _, E .— N co to co P W 0) 0 .- N N N N N N N N N N M M C�) M C) M M C) M M C U N I N N G p C CO N CO CD ON R O U O 44. c a/ r O 0 00 0 O) 0 co 0)rn p) O o W O f`6 . E C O a C\I J N 'E a) a) o W �Iv Q 0 w Q 0 Q � 0 a QCD i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr ing Services LIS Scat_ ,tility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 20 13:36: 17 2012 Reel Header Service name LISTPE Date 12/04/20 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/04/20 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 Alpine MWD/MAD LOGS WELL NAME: CD3-119 API NUMBER: 501032065300 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 20-APR-12 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: -XX-0008520721 -XX-0008520721 LOGGING ENGINEER: PAUL ORTH PAUL ORTH OPERATOR WITNESS: DAVE BURLEY DONNIE LUTRI SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 3984 FSL: FEL: 1030 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 50.32 GROUND LEVEL: 12.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.750 7. 625 15242.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS E BIT DEPTHS UNLESS OTHERWISE . ED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . ONLY INVERT/ REVERT SECTIONS (IF ANY) GREATER THAN 30' TVD ARE PRESENTED. 3. THE SURFACE, PILOT-HOLE, AND INTERMEDIATE SECTIONS OF THIS WELL WERE DRILLED BY SCHLUMBERGER. SPERRY DRILLING RUN 1 DRILLED THE STAGE COLLAR AND CLEANED OUT THE 7. 625" CASING TO THE SHOE AT 15,242'MD/6753'TVD. NO MWD TOOLS WERE INCLUDED IN THE BHA - NO DATA ARE PRESENTED. 4 . MWD RUNS 2, 3 COMPRISED DIRECTIONAL, GAMMA MODULE (GM) WITH GEIGER -MUELLER TUBE DETECTORS, AZIMUTHAL DEEP RESISTIVITY (ADR) , DRILL STRING DYNAMICS SENSOR (DDSr) , PRESSURE WHILE DRILLING (PWD) , AND GEO-PILOT ROTARY STEERABLE BHA (GP) . 5. 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 (SD) ON 27 APRIL 2005. 6. MWD RUNS 1-3 REPRESENT WELL CD3-119 WITH API#: 50-103-20653-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19, 375'MD/6772'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR OR GM COMBINED GAMMA RAY AH1P/ARH16P AVG 16 INCH 2M PHASE RESISTIVITY AH2P/ARH32P AVG 32 INCH 2M PHASE RESISTIVITY AM3P/ARM48P AVG 48 INCH 500K PHASE RESISTIVITY ADXT ADR FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROPA AND DGRC. 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 12/04/20 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 15165.5 19297.5 FET 15225.0 19320.0 AH2P 15225.0 19320.0 AH1P 15225.0 19320.0 AM3P 15225.0 19320.0 ROP 15242.5 19375.0 $ 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 2 15165.5 15844 .0 MWD 3 15844 .0 19375.0 $ 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 FET MWD HR 4 1 68 4 2 AH1P MWD OHMM 4 1 68 8 3 AH2P MWD OHMM 4 1 68 12 4 AM3P MWD OHMM 4 1 68 16 5 GR MWD API 4 1 68 20 6 ROP MWD FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15165.5 19375 17270.3 8420 15165.5 19375 FET MWD HR 0.55 46.25 1.79297 8191 15225 19320 AH1P MWD OHMM 0.02 4090.77 11.6453 8191 15225 19320 AH2P MWD OHMM 0.04 23.32 11.8636 8191 15225 19320 AM3P MWD OHMM 0.02 875.04 12.5837 8191 15225 19320 GR MWD API 31.53 151.71 63.3694 8265 15165.5 19297.5 ROP MWD FPH 0. 62 264.04 81.2819 8266 15242.5 19375 First Reading For Entire File 15165.5 Last Reading For Entire File 19375 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/20 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 12/04/20 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GMGR 15165.5 15766.5 AM3P 15225.0 15789.0 AH2P 15225.0 15789.0 AH1P 15225.0 15789.0 ADXT 15225.0 15789.0 ROPA 15242.5 15844 .0 LOG HEADER DATA DATE LOGGED: 10-APR-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15844.0 TOP LOG INTERVAL (FT) : 15242.0 BOTTOM LOG INTERVAL (FT) : 15844 .0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 81.5 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 10450012 ADR Azimuthal Deep Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 15242.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.80 MUD VISCOSITY (S) : 42.0 MUD PH: 9. 1 MUD CHLORIDES (PPM) : 87000 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .100 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 150.8 MUD FILTRATE AT MT: . 100 68.0 MUD CAKE AT MT: .110 68.0 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 FET MWD020 HR 4 1 68 4 2 AH1P MWD020 OHMM 4 1 68 8 3 AH2P MWD020 OHMM 4 1 68 12 4 AM3P MWD020 OHMM 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 ROP MWD020 FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15165.5 15844 15504.8 1358 15165.5 15844 FET MWD020 HR 0.56 7. 67 1.42422 1129 15225 15789 AH1P MWD020 OHMM 0.02 4090.77 16. 654 1129 15225 15789 AH2P MWD020 OHMM 0.04 23.32 13.6444 1129 15225 15789 AM3P MWD020 OHMM 0.02 875.04 15.28 1129 15225 15789 GR MWD020 API 31.53 103. 69 53.5946 1203 15165.5 15766.5 ROP MWD020 FPH 0. 62 264.04 80.8063 1204 15242.5 15844 First Reading For Entire File 15165.5 Last Reading For Entire File 15844 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/20 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 12/04/20 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GMGR 15767.0 19297.5 AH2P 15789.5 19320.0 ADXT 15789.5 19320.0 AH1P 15789.5 19320.0 AM3P 15789.5 19320.0 ROPA 15844.5 19375.0 LOG HEADER DATA DATE LOGGED: 15-APR-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 19375.0 TOP LOG INTERVAL (FT) : 15844 .0 BOTTOM LOG INTERVAL (FT) : 19375.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 92.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 10450012 ADR Azimuthal Deep Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 15242.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.10 MUD VISCOSITY (S) : 42.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 102000 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .090 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .040 179. 6 MUD FILTRATE AT MT: .100 68.0 MUD CAKE AT MT: .120 68.0 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 .lIN 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 FET MWD030 HR 4 1 68 4 2 AH1P MWD030 OHMM 4 1 68 8 3 AH2P MWD030 OHMM 4 1 68 12 4 AM3P MWD030 OHMM 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 ROP MWD030 FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15767 19375 17571 7217 15767 19375 FET MWD030 HR 0.55 46.25 1.85192 7062 15789.5 19320 AH1P MWD030 OHMM 4 .26 19.26 10.8446 7062 15789.5 19320 AH2P MWD030 OHMM 5.35 18.17 11.5789 7062 15789.5 19320 AM3P MWD030 OHMM 5.29 18.22 12.1526 7062 15789.5 19320 GR MWD030 API 37. 95 151.71 65.0345 7062 15767 19297.5 ROP MWD030 FPH 3.43 197.28 81.363 7062 15844.5 19375 First Reading For Entire File 15767 Last Reading For Entire File 19375 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/20 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 12/04/20 Origin STS Tape Name UNKNOWN Continuation Number Next Tape Name _d KNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/04/20 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
