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209-153
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,409 feet None feet true vertical 7,029 feet None feet Effective Depth measured 15,399 feet 8,720 feet true vertical 7,027 feet 6,928 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8766' MD 6,958' TVD Packers and SSSV (type, measured and true vertical depth)8,720' MD 2198' MD 6,929' TVD 2,097' 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: 3.5" 2023 perfs: 6972-6972', 6988-6988', 6995-6995' 2024 perfs: 6989'-6989', 7034-7035', 7046'-7047' TVD 2685 2485 Burst Collapse Liner 9096' 6679' Casing 6958 7029 9130 15399 2648' 114Conductor Surface measured TVD 7" Plugs Junk measured Length measured true vertical Packer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-153 50-103-20609-00-00 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 372105 Alpine Pool CRU CD3-122 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 461 Gas-Mcf MD 745 Size 114 26 5931409 259 21626 221 Intermediate 24" 9.625" 77' N/A Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1745 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Liner Top Packer 5"x7" SSSV 3.5" Camco TRMAXXX-5E (SSSV locked-out) Mark Shulman mark.shulman@cop.com (907) 263-3782Sr. Production Engineer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 2023 perfs: 10,000-10,020, 11,500-11,520', 12,500-12520' 2024 perfs: 10,600'-10,620', 14,400'-14,420' and 15,000-15,020' MD Fra O s 6. A PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:39 am, Apr 23, 2024 Mark Shulman Digitally signed by Mark Shulman Date: 2024.04.22 17:11:57 -08'00' Adobe Acrobat Reader version: 2024.001.20643 RBDMS JSB 043024 DSR-4/23/24 CD3-122 Perforations DTTMSTART JOBTYP SUMMARYOPS 3/30/2024 MAINTAIN WELL LRS PUMPED 50 bbls CRUDE DOWN TBG, MADE 2 ATTEMPTS w/ OVERSIZED STANDARD PKG< TAGGED SSSV NIPPLE @ 2197' RKB, SET 3-1/2" WRDP W/ 2 SETS FRUITENBERG PACKING @ 2197' RKB (SN: HVS-123 OAL LIH: 89") UNABLE TO TEST DUE TO WELL ON VAC, DSO NOTIFIED. JOB COMPLETE 3/29/2024 MAINTAIN WELL BRUSH & FLUSH TBG W/ 35 bbls CRUDE, MADE 2 ATTEMPTS TO SET 3-1/2" WRDP w/o SUCCESS, JOB INPROGRESS 3/27/2024 MAINTAIN WELL RUN 20' PERF GUNS (6 SPF, 2006 PJ OMEGA 60* PHASE, 7.3GM), SHOOT INTERVAL'S FROM 15,000-15,020', 14,400-14,420, AND 10,600-10,620. ALL SHOTS FIRED. WELL READY FOR SLICKLINE TO SET WRDP. 3/26/2024 MAINTAIN WELL PERFORM WEEKLY BOP TEST, PULL WRDP @ 2198'; FCO/DRIFT W/ 2.68" 5 BLADE JUNK MILL DOWN TO LOCK UP 14,991' CTMD. RIH W/ 2" X 20' PERF, GUN CT CURRENTLY @ 7000' W/ TARGET DEPTH OF 15,100'. IN PROGRESS. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD3-122 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post APERF, Set WRDP CD3-122 3/30/2024 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: ALL SCREENS IN LINER = RESLINK 316L 12 GAUGE WIREWRAP SCREEN w/ RESMAN TRACER 9/7/2012 ninam 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 24" Insulated 16 15.2537.0 114.0 114.062.50 H-40 Welded SURFACE 9 5/88.83 36.12,685.12,484.8 40.00 L-80 BTC-m INTERMEDIATE 7 6.28 33.6 9,130.0 6,958.2 26.00 L-80 BTC-m GRAVEL PACK LINER 3 1/2 2.99 8,720.0 15,399.0 7,029.3 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.5 Set Depth… 8,766.1 Set Depth… 6,935.6 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m 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) 132.6 132.6 0.80 XO - Reducing 4.500 Crossover 4-1/2" 12.6 ppf L-80 box x 3-1/2" 9.3 ppf L-80 pin Unique CPAI PN 1054194 7 2.992 2,197.9 2,096.9 33.34 SAFETY VLV **Locked Out 04/25/2022** 5.1763-1/2" Camco TRMAXX-5E SSSV w/ 2.813" X profile **LOCKED OUT 04/25/2022** Camco TRM-5E x profile, ser # CXS- 0233 2.812 3,874.63,421.5 37.15 GAS LIFT 5.390 Camco 3-1/2" KBMG GLM Camco KBMG2.920 6,650.5 5,611.2 37.93 GAS LIFT 5.390 Camco 3-1/2" KBMG GLM Camco KBMG 2.920 8,325.86,813.065.82 GAS LIFT 5.390 Camco 3-1/2" KBMG GLM Camco KBMG2.920 8,406.1 6,844.3 68.53 NIPPLE 4.540 Camco D Nipple (2.75" min ID) Camco D nipple, PN 1342751 , ser #T12082 7 2.750 8,728.3 6,930.2 81.04 LOCATOR 4.000 Locator Baker 2.990 8,729.5 6,930.3 81.09 Spacer Tube 4.000 Baker GBH-22 80-40 Spacer tube Baker H02- 67262- 00 3.000 8,734.6 6,931.1 81.29 Spacer Tube 4.000 Baker GBH-22 80-40 Spacer tube Baker H02- 67262- 01 3.000 8,744.6 6,932.6 81.69 Spacer Tube 4.000 Baker GBH-22 80-40 Spacer tube Baker H02- 67262- 01 3.000 8,754.7 6,934.0 82.09 SEAL ASSY 4.000 BakerGBH-22 80-40 Bonded Seal assembly BakerH450-01 -4081 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) 2,197.9 2,096.9 33.34 WR-SSSV 2.813" X Lock- 30.5" extenstion- 3.5" WRDP-1 w/ 2 sets Fruitenberg Packing Camco WRDP-1 HVS- 123 3/30/2024 1.500 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) 3,874.63,421.5 37.15 1 GAS LIFT DMY BK-5 1 0.02/27/2010 0.000 6,650.5 5,611.2 37.93 2 GAS LIFT GLV BK-5 1 1,677.0 2/27/2010 0.188 8,325.8 6,813.0 65.82 3 GAS LIFT OVBK 1 0.08/8/2012 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) 8,720.06,928.880.71 PACKER 5.970 Baker 5" x 7" ZXP liner top packer 4.380 8,740.5 6,932.0 81.53 NIPPLE 5.650 RS Nipple 4.250 8,771.7 6,936.3 82.77 XO - Enlarging 5.000 Crossover 5" BTC x 3-1/2" SLHT 2.950 9,801.5 6,968.1 89.37 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 2.15" ID (BALL SEAT MILLED TO 2.75" 5/3/2011l) 2.720 10,423.7 6,983.1 86.68 Swell Packer 5.750 TAM Swell Packer 3-1/2" SLHT 2.992 10,832.6 6,989.1 89.98 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 2.025" ID (BALL SEAT MILLED TO 2.75" 5/3/2011l) 2.720 11,295.36,989.390.72Swell Packer 5.750 TAM Swell Packer 3-1/2" SLHT 2.992 11,738.1 6,989.3 89.05 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 1.90" ID (BALL SEAT MILLED TO 2.75" 5/3/2011l) 2.720 12,199.5 6,989.4 89.51 Swell Packer 5.750 TAM Swell Packer 3-1/2" SLHT 2.992 HORIZONTAL, CD3-122, 3/31/2024 5:50:40 AM Vertical schematic (actual) GRAVEL PACK LINER; 8,720.0- 15,399.0 Float Shoe; 15,398.4-15,399.0 APERF; 15,000.0-15,020.0 SCREEN; 14,596.6-14,607.9 FRAC PORT; 14,588.4-14,592.4 SCREEN; 14,573.3-14,584.7 APERF; 14,400.0-14,420.0 Swell Packer; 13,862.7-13,868.4 SCREEN; 13,528.3-13,539.7 FRAC PORT; 13,520.2-13,524.2 SCREEN; 13,505.1-13,516.5 Swell Packer; 13,108.9-13,114.6 SCREEN; 12,649.4-12,660.8 FRAC PORT; 12,641.3-12,645.2 SCREEN; 12,626.2-12,637.5 FRAC; 10,441.0 APERF; 12,500.0-12,520.0 Swell Packer; 12,199.5-12,205.1 SCREEN; 11,746.3-11,757.6 FRAC PORT; 11,738.1-11,742.1 SCREEN; 11,723.0-11,734.4 APERF; 11,500.0-11,520.0 Swell Packer; 11,295.3-11,301.0 SCREEN; 10,840.7-10,852.0 FRAC PORT; 10,832.6-10,836.5 SCREEN; 10,817.5-10,828.8 Pup Joint; 10,807.6-10,813.3 APERF; 10,600.0-10,620.0 Swell Packer; 10,423.7-10,429.3 APERF; 10,000.0-10,020.0 SCREEN; 9,809.6-9,820.9 FRAC PORT; 9,801.5-9,805.5 SCREEN; 9,786.5-9,797.8 INTERMEDIATE; 33.6-9,130.0 Float Shoe; 9,127.9-9,130.0 Float Collar; 9,042.4-9,043.4 Landing Collar; 8,997.9-8,998.9 SBE; 8,752.6-8,771.7 SEAL ASSY; 8,754.7 Spacer Tube; 8,744.6 HANGER; 8,743.5-8,752.6 NIPPLE; 8,740.6-8,743.5 Spacer Tube; 8,734.6 Spacer Tube; 8,729.5 PACKER; 8,720.0-8,740.6 LOCATOR; 8,728.3 NIPPLE; 8,406.1 GAS LIFT; 8,325.8 GAS LIFT; 6,650.5 Collar; 5,192.6-5,195.1 GAS LIFT; 3,874.6 SURFACE; 36.1-2,685.1 Float Shoe; 2,682.9-2,685.1 Float Collar; 2,603.8-2,605.1 WR-SSSV; 2,197.9 SAFETY VLV **Locked Out 04/25/2022**; 2,197.9 CONDUCTOR 24" Insulated; 37.0-114.0 Casing Hanger; 36.1-38.6 Casing Hanger; 33.6-34.9 Tubing Hanger; 30.5 WNS PROD KB-Grd (ft) 40.90 RR Date 2/5/2010 Other Elev… CD3-122 ... TD Act Btm (ftKB) 15,409.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032060900 Wellbore Status PROD Max Angle & MD Incl (°) 93.82 MD (ftKB) 15,246.95 WELLNAME WELLBORE 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) 12,641.3 6,996.3 89.79 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 1.775" ID (BALL SEAT MILLED TO 2.75" 5/3/2011l) 2.720 13,108.9 6,998.3 89.79 Swell Packer 5.750 TAM Swell Packer 3-1/2" SLHT 2.992 13,520.2 7,009.8 88.25 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 1.650" ID (1.75" Ball) MILLED SLEEVE TO 2.70" ID 3/26/2023 2.700 13,862.7 7,019.2 89.12 Swell Packer 5.750 TAM Swell Packer 3-1/2" SLHT 2.992 14,588.4 7,038.0 89.59 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.35" OD x 1.525" ID (1.625" Ball) MILLED SLEEVE TO 2.70" 3/26/2023 2.700 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,000.010,020.06,972.16,972.23/25/2023 6.0 APERF 2" POWERJET OMEGA 2006, 6SPF, 60* PHASING. 10,600.0 10,620.0 6,989.1 6,989.2 3/27/2024 6.0 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 11,500.0 11,520.0 6,987.9 6,987.9 3/25/2023 6.0 APERF 2" POWERJET OMEGA 2006, 6SPF, 60* PHASING. 12,500.0 12,520.0 6,994.8 6,995.0 3/25/2023 6.0 APERF 2" POWERJET OMEGA 2006, 6SPF, 60* PHASING. 14,400.0 14,420.0 7,034.1 7,034.7 3/27/2024 6.0 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 15,000.015,020.0 7,046.5 7,046.7 3/27/2024 6.0 APERF 20', 2.0" GUNS~ 6 SPF, 60 DEG PHASE, 2006 PJ OMEGA HMX, 7.3 GM, .22" ENT HOLE, 21.80" PENETRATION. 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) 10,441.0 14,594.0 1 FRAC 2/25/20100.00.00 0.00 HORIZONTAL, CD3-122, 3/31/2024 5:50:44 AM Vertical schematic (actual) GRAVEL PACK LINER; 8,720.0- 15,399.0 Float Shoe; 15,398.4-15,399.0 APERF; 15,000.0-15,020.0 SCREEN; 14,596.6-14,607.9 FRAC PORT; 14,588.4-14,592.4 SCREEN; 14,573.3-14,584.7 APERF; 14,400.0-14,420.0 Swell Packer; 13,862.7-13,868.4 SCREEN; 13,528.3-13,539.7 FRAC PORT; 13,520.2-13,524.2 SCREEN; 13,505.1-13,516.5 Swell Packer; 13,108.9-13,114.6 SCREEN; 12,649.4-12,660.8 FRAC PORT; 12,641.3-12,645.2 SCREEN; 12,626.2-12,637.5 FRAC; 10,441.0 APERF; 12,500.0-12,520.0 Swell Packer; 12,199.5-12,205.1 SCREEN; 11,746.3-11,757.6 FRAC PORT; 11,738.1-11,742.1 SCREEN; 11,723.0-11,734.4 APERF; 11,500.0-11,520.0 Swell Packer; 11,295.3-11,301.0 SCREEN; 10,840.7-10,852.0 FRAC PORT; 10,832.6-10,836.5 SCREEN; 10,817.5-10,828.8 Pup Joint; 10,807.6-10,813.3 APERF; 10,600.0-10,620.0 Swell Packer; 10,423.7-10,429.3 APERF; 10,000.0-10,020.0 SCREEN; 9,809.6-9,820.9 FRAC PORT; 9,801.5-9,805.5 SCREEN; 9,786.5-9,797.8 INTERMEDIATE; 33.6-9,130.0 Float Shoe; 9,127.9-9,130.0 Float Collar; 9,042.4-9,043.4 Landing Collar; 8,997.9-8,998.9 SBE; 8,752.6-8,771.7 SEAL ASSY; 8,754.7 Spacer Tube; 8,744.6 HANGER; 8,743.5-8,752.6 NIPPLE; 8,740.6-8,743.5 Spacer Tube; 8,734.6 Spacer Tube; 8,729.5 PACKER; 8,720.0-8,740.6 LOCATOR; 8,728.3 NIPPLE; 8,406.1 GAS LIFT; 8,325.8 GAS LIFT; 6,650.5 Collar; 5,192.6-5,195.1 GAS LIFT; 3,874.6 SURFACE; 36.1-2,685.1 Float Shoe; 2,682.9-2,685.1 Float Collar; 2,603.8-2,605.1 WR-SSSV; 2,197.9 SAFETY VLV **Locked Out 04/25/2022**; 2,197.9 CONDUCTOR 24" Insulated; 37.0-114.0 Casing Hanger; 36.1-38.6 Casing Hanger; 33.6-34.9 Tubing Hanger; 30.5 WNS PROD CD3-122 ... WELLNAME WELLBORE C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-02-27_23067_CRU_CD3-122_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23067 CRU CD3-122 50-103-20609-00 Col Flag 27-Feb-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 209-153 T40205 3/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.10 11:03:35 -08'00' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Kayfa Junke at 10:03 am, Apr 05, 2023 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Susp Well Insp ❑ Plug Perforations Fracture Stimulate C Pull Tubing U Operations shutdown Performed: Install Whipstock Perforate J Other Stimulate ❑ Alter Casing Change Approved Program I 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 ❑ Stratigraphic _ Exploratory ❑ Service ❑ 209-153 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20609-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105 CRU CD3-122 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 15,409 feet Plugs measured None feet true vertical 7,029 feet Junk measured None feet Effective Depth measured 15,399 feet Packer measured 8,720 feet true vertical 7,027 feet true vertical 6,928 feet Casing Length Size MD TVD Burst Collapse Conductor 77' 24" 114 114 Surface 2648' 9.625" 2685 2485 Intermediate 9093' 7" 9130 6958 Liner 6679' 3.5" 15399 7029 Perforation depth Measured depth 10000-f e020', 11,500-11,520' and 12,500-12,520' MD True Vertical depth 6972-6972%69W8 988%6995 996TVD Tubing (size, grade, measured and true vertical depth) 3.5" L-80 134' x 8766' MD 6,958' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Liner Top Packer 5"x7" 8,720' MD 6,929' TVD SSSV 3.5" Camco TRMAXXX-5E (SSSV 2198' MD 2,097' TVD locked -out) 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: 1 249 1 1025 37 1 955 1 249 Subsequent to operation: 1227 1 1530 395 1 1147 1 663 13b. Pools active after work: 14. Attachments (required per 20 AAC 25.070. 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL LJ Electronic Fracture Stimulation Data ❑ GSTOR I I WINJ ❑ WAG ❑ GINJ 7 SUSP SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Digitally signed by Mark Authorized Name and Mark Shulman Shulman N/A Digital Signature with Date: Date: 2023.04.0417:24:02 -08'00' Contact Name: Mark Shulman Contact Email: mark.shulman(S212.c m Authorized Title: Sr. Production Engineer Contact Phone: (907) 263-3782 Sr Pet Eng: I ISr Pet Geo: I ISr Res Eng: DSR-4/6/23 RBDMS JSB 040623 Form 10404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov CD3-122 Perforations DTTMSTART JOBTYP SUMMARYOPS 3/31/2023 MAINTAIN WELL BRUSH PROFILE @ 2198' RKB. SET 3-1/2" WRDP-1 ON 2.813" X-LOCK @ 2198' RKB. PERFORM PASSING DDT. JOB COMPLETE. 3/26/2023 MAINTAIN WELL MILL LOWER FRAC SLEEVE AT 14588' TO 2.70", FREEZE PROTECT WELL, RDMO. TURN OVER TO OPS 3/25/2023 MAINTAIN WELL DID NOT GET FRAC SLEEVE @ 14588' MILLED UP, OOH INSPECT TOOLS, MADE UP FIRST PERF GUN, CORRECT DEPTH @ FLAG, SHOOT PERFS (12,500'- 12,520') 2ND PERF RUN SHOOT PERFS (11,500'-11,520') 3RD PERF RUN SHOOT PERFS (10,000'-10,020'), 2.0" POWERJET OMEGA 2006 CHARGES, 6 SPF, 60 DEGREE RANDOM PHASING. 3/24/2023 MAINTAIN WELL RIG UP CTU 11, PERFORM WEEKLY BOP TEST, RECOVERED WRDP AT 2197' CTMD, PU MOTOR/MILL, TAG AT 12,867' MILL DOWN TO FRAC SLEEVE @ 13520', WITH MINIMAL TO NO MOTOR WORK. TALK WITH ENGINEER ABOUT MILLING THE LAST TWO FRAC SLEEVES @ 13520' AND 14588'.TO 2.66", DECISION WAS MADE TO MILL THEM OUT. MILL FRAC SLEEVE @ 13520' TO 2.66", CRIH AND TAG FRAC SLEEVE @14588'. JOB IN PROGRESS. WINS PROD WELLNAME CD3-122 WELLBORE CD3-122 �-ormci Phill'MS Well Attributes Max Angle & MD TO �WVIIIVMt.VVf11 P AI85ka,nD. Fione Name Well bore APIIDWI Wellbore Status Icl rl 3 82 MD(XKBI 15,24E 95 ACI Ron 15,409.0 IRK-1 <wy,4, Comment H23(Pa. Data Annotation End Data KD.G,a(ml RROah Othe, El - Last WO. 4090 25I2010 KORIEOm AL, CDSL= M ciacc 5'.SI MAM Vstlol¢nemvlk lami Annotation Depth(fthm Wellbore End Data last SEE By Last Tag: CD}122 Imosbor 1,ese ment, a_ Last Rev Reason ............................................................. ............ cseiie Hene�. S1.634.0 Ann.... wallbore Eha wle lea Moa ey Rev Reason: SET WRDP CD}122 3I3V2023 ohe„ Ran .."..a Notes: General & Safety cGNDUCTGR2d'Innl . 37.0-114.0 an.... Ena Dale Lasl Moa By NOTE '. ALL SCREENS IN ILITNER= RESUNK 31612 GAUGE WIREWPAP SCREEN w/RESMAN 90I2012 ninam RACER 6AFETvvlv•Mmkel Cut Casing Strings DarzEGDa-z+SAe wksssv;;le].e SetDepthset Depth Csg De. OD (in) ID IN Top (mkel InKDI (rvDI gIKD) wuLen lllanl Greae Top .trees CONDUCTOR 24" Insulated 16 15.25 3J.0 114.0 114.0 62.W H-4D Welded eca Center z®e-alaxv Fbn sb, ; �.6;Ia51 STRFACe,..11:. SURFACE 95/8 6.83 36.1 2.665.1 2,464.8 40.00 L-80 BTGm INTERMEDIATE J 6.2E 33.E 9,130.0 6,956.2 26.00 L-80 BTC-m GAS LIFT; aeu6 -GRAVEL PACK 31/P 2.99 6,1ZU.0 15,399.0 1,029.3 9.30 L-80 51-111 LINER I 1 Tubing Strings: string max Indicates LONGEST segment of string Cqs, S+sSas.15'1 Top(ftnq set Depth- set Depth sting Ma... Tubing DesnNption Wl6brml G,eae Tap Connectbn ID lint lathing 30.5 8, 766.1 6,935E 31/2 TUBING 9.30 L-80 EUPEC T. GAS LIFT.S.5 Completion Details: excludes tubing, pup, space out, thread, RKB... OD Top RVD) ml t Nummal Nominal Shoe LIFT.S.Ra Top (al MR.) ('I Ihm Des Ilnl Com Mq[e Moaq ID (n) 132.6 132.6 0.80 XO- Redudng 4,500 Cmssver 4-1Y2"12.6 pp1 L-80 box Unique CPAI 2,992 31IT 9.3 ppf L-80 pin PIN NIPPLE; aLseA 1054194 J LOCATOR; a"he PAKER S.. Tuse.,]im.s c. spe. TW; a]aa.6 2197,9 2,096.9 33.M SAFETYVLV "Loathed ON OM2 XQ2' 5.176 1VZ'Camm TRMAXX-5E SSSV Camco w/2.813"Xpmfile'40CKEDOUT OM2 122' TRMSE xprofle, set# 2.812 NIPPLE, a...:..a CxS- HPNGER,B]43.5$]526 0233 Knew, Tubes: 0.. 3,814.6 3,421.5 3J.15 GAS LIFT 5,390 Camco 3-1Z KBMG GLM w/1" Camco KBMG 2.920 EALAKSv,R..] sae, A75z.6a,nv dummy valve w/ BKS Latch 6,650.5 5,611.2 37.93 GAS LIFT 5,390 Camco 3-1KBMG G w/1' Camco KBMG 2.920 dummyvalve WBKSLatch la,ans Chun eew.sa,®ea 8,325.8 6,813.0 65.82 GAS LIFT 5.390 Camco 1lNAME G w/ C -2 Camco KBMG 2.920 Flew C.I.. eoa;4a,Iua4 a BEK-5 Latch - VaWe Sheared Fee Kbw,e S1AGjSD.0 IN Fee 8,406.1 6,644.3 68.53 NIPPLE 4.540 Camco D Ni 2.J5"minD Oamco pWe( ) n PIN 2.J50 1342751 .as SCREEN, swa.3q,] . #1-12082 FMC PORT', 98015a.8has I� J scREEN, ROmse,mD.e 87283 6,930.2 81.04 LOCATOR 4.000 Locator Baker 2.990 APERFpgomnm,mo.o- 8,729.5 6.930.3 81.09 Spam Tube 4,000 Baker GBH-2280.405peCer tube Baker D2- 6J262- 3.000 SwelPenilg4m]-+gdm.a 00 8,734.6 6,931.1 81.29 Spacer Tube 4,000 Baker GBH-2280.40 Spacer tube Baker O2- 3.000 PupanE San ma 67262- 01 SCREEN; 1gOtZs1ga20.0 874.6 6,932.6 81.69 Spam Tube 4,000 Baker GBH-2280.40 Spacer tube Baker O2- 3.000 FIAC POW; 1 gflR61n,fli6.5 67262- 01 SCREEN; 1gOb.17-1g05;D 8,J54J 6.934.0 82.09 SEALASSY 4,000 BakerGBH-22 8040 armed Seal Baker H4 0.01 3.000 Red Pacbr, 11,3B5.311,m1.0 Ksurady 4081 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PPERF; 1+,5mn+y5mD Top ITVD) I I Tap lhKBl IPKB) Top lnd (•1 Des Com Make a.-SN Run Oate IO tint 2.191.9 40969 33.64 Wf3-SSSV 2.813"%Lock-30." CAMCO WRDP-1 C15S 3131/2023 1`nA SCREEN;1;]mn1t,]a44 extenslim-3.5" WRDP-1 wl 0518 1 FRAC POW. 11,]a9.1-11,]421 I� Y I slandaN ovens Chevron packing ana to d al SCREEN; 11,]46.311,]5/.6 Mandrel Inserts : excludes pulled Inserts Real Packer, 1 z1WsnZat 1 51 APERF;1;Sm LL1;5mo FRAC; 1g441O Tap ImKDI Top RVD) MKD) rap on In.1r N valve Sery Type Latch Type OD on) TED Run (pas Run Data Com Make MWel Port She In) 3,1.6 3,d21.5 3J.15 1 GAS LIFT DMV BK-5 1 0.0 2I2JI2012 0.000 6,650.5 5,6112 3J.93 2 GAS LIFT GLV BK-5 1 1,671 2/,,010 0.188 SCREEN; 1ZEIS -Zuna I8' I 6,325.E 6813.0 I 65.IC 3 GASLIFT UV BK 'I 0.0 Snnu12 0250 FI POW;1Zmh,S12.D432(((1BBBIlltR Liner Details: Excludes Liner, Pup, Joints, casing, goat, sub, shoe... SCREEN; lZms4lZal OD Top(TVD) Top Nominal Nominal S`mlPackr,lal®.P1a11I.6 Top NtKIN net l-) man Des (In) Com Meke MMq ID (in) 8,720.0 6928.E 80.71 PACKER 5,970 Baker S"x J" ZXP liner top packer 4,380 8.740.5 6.932.0 81.53 NIPPLE 5.650 RS Nipple 4.250 scREEN;1a5aK t-1a51Rs ga 8771.7 69363 82.77 XO-Enlarging 5.000 Crossover 5"BTCit 3-I/2"5LHT 2.950 F. PORTpasmalaszaa 9,801.5 6,968.1 89.37 FRAC PORT 4.350 Baka Ba Actuated Seeve 4.35" 2.720 SCREEN. 1asss0.1as ..] OD x 2.15' ID (BALL SEAT MILLED TO 2.75" WN20111) Red Pe`ke'' 13eQ1a0614 10,423.7 6.983.1 86.68 Swell Packer 5.750 TAM Swell Packer YIZ SLRT 2.992 10,B32.6 6,989.1 89.98 FRAC PORT 4,350 Baker Ball Aduated Sleeve 4.35" 2.720 OD x 2.025' ID (BALL SEAT SCREEN; 1,t OSs14sa4.] MILLED TO 2]5" 51120111) FRAC POW; 14,9s0.4-14.58B4 11,295,31 6,989,31 90,72 ISSRII Packer 1 5.750 1 TAM Swell Packer Y1/ SLHT 2.992 SCREEN; 14,5W614,1301e F�SM1w;133W 415,�B,C� 1 GRMrEL PACK LINER; 0,]30.0. 1s.aePa WNS PROD WELLNAME CD3-122 WELLBORE CD3-122 cono� PF,inips aaska, Inc. NONEONTAL, Ccai Ancei San AM Liner Details: Excludes Liner, Pup, Joints, cast vmam maeml. l.m.n Top NINE)8.16,939 Tap(NDI Top trial39.05 Rem Des OD me Nominal li. Lod Make Mctlel Nominal ID llnl TdYry Nenper, a9s� 11 ]38.1 6,989.3 89.05 FRAC PORT 4.350 Baker Ballto(BActuated Sleeve 4.35" 2.720 ............................................................. ............. OD ID (BALL SEAT cmee Nw... Sa601e MILLED DT T02J5" 5I320111) eaele N �; xlaes 12,199.5 6,989A 89.51 Swell Packer 5.750 TAM Swell Packer 3312"SLHT 2.992 CONDUCLOR N'Im�,Mb1; n.wtl.a 12641.3 6,996.3 89.79 FRAC PORT 4.350 a dals ru 2.]20 OD xt.]]5" ID (BALLLL SEAT SAFFTV VLv-Lack.a on MILLED TO 2.75" 511 OIrzomeral. 21WA wassv 2lw.e 13,108.9 6,998.3 89.79 Swell Packer 5.750 TAM Swell Packer 3P12"SLHT 2.992 13,520.2 7,009.8 33.25 FRAC PORT 4.350 Baker Ball Actuated Sleeve 4.W' 2300 ODx 1.650. 1D (1]5" Ball) real Calls, 2�azeel Fear Skm:?S%?Guar1 MILLED SLEEVE TO 2.70" ID SURFACE; 3s1-? sd 326R023 A. u, Sale s 13,862.7 7,019.2 89.12 Swell Packer 5.750 TAM Swell Packer 312" SLHT 2.992 14,588.4 7,038.0 89.59 FRAC PORT 4.350 BakerActuated Sleeve 4.35' 2700 OD 1.525"ID (1.625"Ball) Li.r, 5,19266,195.1 MILLED SLEEVE TO 2.70" SAS OFT; ADi 3126,2023 Perforations & Slots aAS OFT; g3Ee Sh. TOPlrvol Bromell Den: Tap lnxal 61m1Ke1 a Inxel IM1e1 unxeazane Dale lebonml Type Cam NIPPLE, Small _ 10,000.0 10,020.0 6,9]2.1 6,9]2.2 1212023 6.0 APERF 2" POW E O GA 2006,6SPF, 60-PHASING. LOCATOR; $]2k.3 11,500.0 11,520.0 6,98].9 6,98].9 12eJ2023 6.0 APERF O O GA PACKER; e,T29.6$]19.6 -1 1729s 2006, 65PF, 60- PHASING. 12,500.0 12,520.0 6,994.8 6,995.0 12eJ2023 6.0 APERF O ERJE O GA NIPP1E;aT106$]13.5 Usui a,T13Ei. 2006, 65PF, 60' PHASING. apes 11 gTaas :a]51T Stimulation Intervals SEE. a 76 M er va Nam PropWnl ProPWnl Vd Clean Vd Blurry IendnP Cher: 0,99]8g8�0 Top mark Bim lYlKal ber Type Subtyye Stan DNe DeslBn 111b1 TendAb) TWI IWII Talal(.4 10,441.0 14,594.0 1 FRAC 2I2eJ2010 0.0 0.00 O.UO FM Coca. 90R.Igcm,4 FM SI,w; Fr21. 1]a.O INTERMEDIATE 336e, 130.O SCREEN; OTeaseTBTH�g FRAC PORT; Sol res� SCREEN; 9,WB ,,M2�B APERF; tO 000.010029.0� mesh Pavker, 19,49.]-1 R4293 P,p Jm[ 19,I1S1.F10ONS SCREEN, 1011 Reva FRAC PORT, 1064.6-10831I� Y SCREEN; 1011 Ca m es Pavker, ll ffi311,391.0 APERF; 115W.D-11,5IDO SCREEN, 11,TD.T11,731A I FMC PORT, 11,]39.1-11,M.1 Igl SCREEN, 11,74xN-11,T51.6 I I mes, Paces, 12,1L@."Liza .1 APERF 12,S00.61?SIDO FMC; 10,1110 SCREEN, 12,626.F1?6l]5 yI FRAC PORT; 1?6113126155 1 SCREEN; 12619.4lZate Igr Seel) Peal 13,109813111.E SCREEN; 13,505.1-135165 FROG PORT; 135A.?1 NEI SCREEN, 13 ESSNL3539.] Seel) Faces,, 13,862.]-13a®A SCREEN, 14ae.314,5611 FROG PORT, I4,583.414,5B2A 11 r SCREEN, 14 SPES-14,W]0 I Franc Ni 1 1 LEAC LINEN5.r' GRAVEL PACK LINER; $TID 6 14]er.0 V\dal -2.0c( _ i53 cp3 -- lea RECEIVED ConocoPhiIIips APR 2 7 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 23, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission SCANNED MA 0 ,1. 2015 333 West 7t1i Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. A s per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, f MJ oveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosic.n inhibitor, Sealant Top-off Report of Sundry Operations(10404) Alpine Field Date 4/23/2015 CD3 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD3-121 50103206150000 2100220 32" NA 32" NA 29.7 3/12/2015 CD3-122 50103206090000 2091530 74" NA 74" NA 49.3 _ 3/12/2015 CD3-130 50103206770000 2131600 38" NA 38" NA 20.4 3/12/2015 CD3-198 50103206370000 2110240 28" NA 15" NA 2.5 3/24/2015 CD3-316 50103205590300 2140180 9" NA 26" NA 14 I 4/20/2015 CD3-320 50103206670000 2130060 6" NA 6" NA 1.7 3/24/2015 I go 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. an q - 1 Well History File Identifier Organizing (done) Two -sided IIIIIIIIIIIIIIIIII ❑ Rescan Needed III I11111 I I R AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: her, No/Type: C. NO, t ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: // Date: Maria �. /s/ (V 1 1 C� Project Proofing IHhIIIIU 11111 BY: Man'a 1 Date: 13 /s/ 11 IP c314 Scanning Preparation g x 30 = + �Q = TOTAL PAGES ca( a g P `T�`� (Count does not include cover sheet) BY: (� Date: a cj ' 3 /s/ Production Scanning I Stage 1 Page Count from Scanned File: aip 3 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: / /5/I is/ wi Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 11111111M ReScanned III 1111111 1 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked I i 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil El Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 311 -035 / 312 -067 2/29/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: • cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 25305 100 384.5* 25789.5 33 totals (bbls): 2012 / 2nd 5840 100 0 5940 6 4/1/2012 4/19/2012 CD3 -119 2012 / 3rd 0 0 0 0 0 2012 / 4th 0 0 0 0 0 2013 / 1st • Total Ending Report is due on the 20th Volume 31145 200 384.5 (bbls): 31729.5 39 of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. t1 12. Remarks and Approved Substances APR ® 9 2013 * Description(s): SCANNED *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signature: j...44& Date: / l67L' r9 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate DATA SUBMITTAL COMPLIANCE REPORT 8/8/2012 Permit to Drill 2091530 Well Name /No. COLVILLE RIV FIORD CD3 -122 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20609 -00 -00 MD 15409 TVD 7029 Completion Date 2/4/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: • Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Me /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 2645 15408 Open 2/24/2010 ED''' Lis 19375 Induction /Resistivity 2645 15408 Open 2/24/2010 OH LIS GR< RPX, RPM, FET, RPS, RPD, ROP, NPHI, NCNT, RHOB, DRHO, PEF, FCNT Plus TIFF, CGM, & PDF Graphics Log Induction /Resistivity 25 Col 114 15408 Open 2/24/2010 MD ROP, DGR, ALD, CTN Log / Induction /Resistivity 25 Col 114 15408 Open 2/24/2010 TVD ROP, DGR, ALD, CTN ED „.4 Asc Directional Survey 36 15408 Open Rpt Directional Survey 36 15408 Open Well Cores /Samples Information: Sample • Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION �ry Well Cored? VG) Daily History Received? .(J�`'"1 n"a Chips Received? 't`"tht` Formation Tops C2/....N l Analysis 1711+ Received? I Comments: DATA SUBMITTAL COMPLIANCE REPORT 8/8/2012 Permit to Drill 2091530 Well Name /No. COLVILLE RIV FIORD CD3 -122 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20609 -00 -00 MD 15409 TVD 7029 Completion Date 2/4/2010 Completion Status 1 -OIL Current Status 1- UIC N -----js Compliance Reviewed By: Date: O _ " 1 L_ s • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 . ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil El Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 312 -067 2/29/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal IIP drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 25305 100 384.5* 25789.5 33 2012 / 2nd 5840 100 0 5940 6 4/1/2012 4/19/2012 CD3 -119 2012 / 3rd 2012 / 4th 2013 / 1st Total Ending Report is due on the 20th Volume 31145 200 384.5 31729.5 39 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: A- c_ 044 Date: 7(6 (z fZ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate RECEIVED STATE OF ALASKA APR 1 1 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL AOGCC 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil 0 Gas WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20609-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final 11 311 -035 / 312 -067 2/29/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: III domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 357* 357 totals (bbls): 2011 / 1st 0 0 0 0 0 2011 / 2nd 0 0 27.5* 27.5 0 2011 / 3rd 0 0 0 0 0 2011 / 4th 0 0 0 0 0 2012/1st 25305 100 0 25405 33 1/21/2012 3/31/2012 CD3 -128, CD3 -119 Total Ending Report is due on the 20th Volume 25305 100 384.5 25789.5 33 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ _ f_orirth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ( f ,,nt Date: COO te.0(L Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: rY rY PP 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 311 -035 3/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred • fluids, formation fluids and any necessary water added Previous 357* 357 totals (bbls): 2011 / 1st 0 0 0 0 0 2011 / 2nd 0 0 27.5* 27.5 0 2011 / 3rd 0 0 0 0 0 2011 / 4th 0 0 0 0 0 2012 / 1st • Total Ending Report is due on the 20th Volume 0 0 384.5 384.5 0 i ll month f o f the monoown the final month of the quarter. Ex: (bbls): 9' q April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is rue and correct to the best of my knowledge. / Signature: -1 Date: (! G (Lo (-Z_ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 RBDMS JAN 0 9 2012 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil El Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 311 -035 3/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 357* 357 ! , totals (bbls): 2011 /1st 0 0 0 0 0 2011 / 2nd 0 0 27.5* 27.5 0 2011 / 3rd 0 0 0 0 0 2011 /4th 2012 / 1st Total Ending Report is due on the 20th Volume 0 0 384.5 384.5 0 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarte 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances - Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signature: A Date: t:' �� r "' l , Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/20F� MS OCT 14 L@Ii INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil 151 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 111 or Final ❑ 311 -035 3/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and Or any necessary water added Previous 357* 357 totals (bbls): 1 2011 / 1st 0 0 0 0 0 2011 / 2nd 0 0 27.5* 27.5 0 2011 / 3rd 11/20 4th 2012 / 1st Total Ending Report is due on the 20th Volume 0 0 384.5 384.5 0 in nth f m o f the month the final month of the quarter. Ex: (bbls): 9 q April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect and injectivity test volumes I hereby certify that the foregoing is true and corr ct to the best of my knowledge. t / z e Signature: At Date: 7 0 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE' OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -153 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -122 2. Address: 4b. Well Status: Oil El Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20609 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal El or Continuation ❑ or Final ❑ 311 -035 3/1/201 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and • any necessary water added Previous 357* 357 totals (bbls): 2011 /1st 0 0 0 0 0 2011 / 2nd 2011 / 3rd 2011 / 4th 2012 / 1st Total Ending Report is due on the 20th Volume 0 0 357 357 0 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect I hereby certify that the foregoin is true s 4(t- and correct to the best of my knowledge. Signature: t% Q Date: I zoo( Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • SEAN PARNELL, GOVERNOR &l.) IT [E [F E / ALASKA OIL AND GrAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Liz Galiunas Supervising Drilling Engineer ConocoPhillips Alaska Inc. PO Box 100360 c a Q - S 3 Anchorage, AK 99510 Re: Colville River Field, Colville River Pool, CD3 -122 Sundry Number: 311 -035 Dear Ms. Galiunas: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair S DATED this / day of March, 2011 Encl. STATE OF ALASKA dattu . l ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION'Y IV r wP ( :;36 r' ;dm' 20 AAC 25.080 • - a 1. Operator 3. Permit to Drill Name: 2091530 ConocoPhillips Alaska 4. API Number: 50- 103 - 20609 -00 • 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -122 • 6. Field: Colville River Field 7. Publidy recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD3 -110, CD3 -106, CD3 -111, CD3 -112, CD3 -113, CD3 -114, CD3 -115, CD3 Torok and Seabee formation, shale, siltstone and sandstone 118, CD3 -117, CD3 -121, CD3 -123, CD3 -125 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1250' MD / 1239' TVD None . 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 357 bbl • densities range from diesel to 12# /gal 2,106 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. ' . Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1- Mar -11 added water needed to facilitate pumping of drilling mud or drilling cuttings and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: is Well Schematic (Include MD and TVD) El Cement Bond Log (if required) III FIT Records w /LOT Graph Surf. Casing Cementing Data El Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Su.PEe.V car 0-14 Signature: / �_.l _.r ■16�'�11 2 1 1 Title: O(24 L- L t n.r Li. -en.) C) 1 k)",--El? Ag e Printed Phone Name: Liz Galiunas Number: 265 -6247 Date: Commission Use Only Conditions of approval: LOT review and approval: .2-de-/I Subsequent form required: ( 0 + 4 12 3 Approval number: . 3 1 t 1 035 • APPROVED BY `� l Approved by: COMMISSIONER THE COMMISSION Date:3/ 1 / pp�� Q R 1 I n �� -�, - z- '3 i! Form 1Q�6/�� 02 2 INSTRUCTIONS ON REVERSE � � � Submit Duplicate y ell 02-Re, ft li.r -7,404 • • Annulus Disposal Transmittal Form - Well CD3 -106 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD3 -122 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1250' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albin Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, March 15. 19991 • 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. A Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2,106 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3 -199, CD3 -127, CD3 -128, CD3 -125, CD3 -198 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0 - In'05 Well CD3 -122 Assumptions Date 2/7/2011 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing /casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 1,000 psi tk Maximum Fluid Density to avoid Burst of Surface Casing u Pburst85% = PHydrostatic + PApplied - PFormation 4,888 = ( 2,485 * 0.052 * MW ) + 1500 - ( 0.4337 * 2,485 ) u7 N MWmax = 34.6 ppg 2,485 TVD . Surface Casing String Size 9.625 in d To Weight 40 ppf d d Grade L 80 A q -( e c e on�� k S r burst100% 5,750 psi gL Nlgo 4 , C .--r- /Nr. 4 � , Pburst85% 4,888 psi /M /Joa mi.o >J • Depth of Shoe 2,485 ft SIt o' FIT/LOT @ Shoe 16.3 ppg or 2,106 psi FIT/LOT for Annulus 14.3 ppg o ° o �4/ / 4 , j • Max Surf. Pressure 1,500 psi _ TOC Est. @ 7,786' MD 6,501' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 6,501 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 6,501 ) - 1,000 Z I MWmax = 13.5 ppg - 3.5 "Tubing 2nd Casing String Size 7 in / \6,958 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,501 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax allowable = ( 2,485 * .052 * 16.3 ) Pmax allowable = 2,106 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". SURFACE CASING SHOE SEPARATION FROM CD3 -122 CD3 -122 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27. 387238.8 6004125.0 V ista ace - Ann. from Surface csg. Surface Details @ Disp. Object Shoe X Surface csg. Surf LOT casing ND Annular Wells AOGCC Permit # Permit Date Source well Ann. Vol. ** Start Date End Date well* Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments CD3 -108 2234 389300.3 6004986.4 11.1 2431 16.9 not for annular disposal CD3 -110, CD3 -111, CD3 -112, CD3 -307, CD3 -109 y 306 -020 CD3 -302 1/20/2006 3/4/2007 1802 388917.3 6004780.2 18.0 2414 16.0 Extended to 70000bb1, exp 03/17/07 CD3 -110 y 1453 388563.7 6004720.7 16.7 2439 15.8 Low surface shoe test CD3 -114, CD3 - 111 y 307 - 066 CD3 - 301 26674 3/20/2007 4/20/2007 l ... 387821.0 6004710.6 17.4 2469 14.6 CD3 -113, CD3- 107/CD3 CD3 -112 y 307 -002 307 32 1/22/2007 3/16/2007 ✓ 3013 387406.8 6004382.6 18.0 2485 15.1 Also known as CD3 -107, second annlus, S CD3- 107/307 y 2392 389627.9 6004245.8 18.2 2479 15.3 after cut and pull operations Feb 2007 CD3 -113, CD3 -118, CD3 -303, CD3 -302 y 308 -036 2/8/2008 CD3 -107L1 56647 2/12/2008 1/1/2010 1614 388815.4 6004469.9 18.0 2505 15.0 CD3 -316, CD3 -113 y 307 -067 3/20/20 CD3 -316A 31964 1/15/2008 3/20/2008 4.5 387636.7 6003901.1 18.0 2475 16.3 CD3 -114 Y � ""11 40$ 387024.7 6003781.8 16.4 2485 14.2 CD3 - 301 y ____. 1902 388541.7 6005510.5 16.2 2493 15.1 Low surface shoe test CD3 -305, CO3 -316A Y 308 -127 4/16/2005 CD3 - 115 31881 1/11/2009 2/16/2009 1729 388868.2 6003548.0 18.0 2476 15.9 CD3 - 303 Y 308 - 426 12/15/2008 CD3 - 117 23833 2/14/2009 3/27/2009 2861 390091.0 6003906.6 18.0 2488 15.9 CD3 -118 Y // - __ 1050 386456.5 6003425.3 16.6 2489 15.7 Low surface shoe test CD3 -305 Y 309 -379 12/1/2009 32000 2/1/2010 3063 390145.4 6003158.0 18.0 2471 14.70 CD3 -115 Y 309 - 087 3/11/2009 CD3 -304 32000 2/1/2010/ 508 386822.0 6003553.0 18.0 2471 13.30 CD3 -304 Y 309 -380 ' 1493 4/1/2010 3667 390789.9 6003209.3 18.0 2472 15.20 CO3.117 Y 1112 386471.4 6003320.0 16.2 2447 14.80 ■ CD3 -106 Y 1261 388447.6 6004482.6 17.0 2475 15.00 CD3 -121 Y 486 387435.6 6004569.9 16.3 2457 14.90 CD3 -122 Y 0 387238.8 6004125.0 16.3 2484 14.30 CD3 -123 N ,/ 310 386932.7 6004176.7 2468 15.20 Low surface shoe test CD3 -124 Y 310 -088 2/1/2010 1454 386016.2 6003338.3 15.9 2472 14.60 Low surface shoe test CD3 -125 622 386683.0 6003845.0 Planned Wells CD3 -127 1103 386211.8 6003723.6 Planned Wells CD3 -128 871 386506.8 6003653.0 Planned Wells CD3 -198 1423 388582.5 6004592.6 Planned Wells • CD3 -199 687 387863.6 6004409.6 Planned Wells * Lateral distance in feet, between surface casing shoes, in the X -Y plane ** As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes ..� . y � e , C D 3 12 2 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) [12.* t etim y w, Name TVDSS +N/ -S +E / -W Northing Easting Shape CD3- 113_SouthwpXX Top Nechelik 6902.00 -314.44 - 3743.68 6003269.00 1524239.00 Circle (Radius: 100.00) Quarter View CD3- 113_SouthwpXX Toe 7025.00 5130.68 - 176.44 5998400.00 1527733.00 Circle (Radius: 100.00) v N 1 10 N N c 4 � GOB' Og G °� G °'� • 106 61 V _ 03 lk _ GQ3,111 7� 06 I GO3 ,301A ‘\ O ��`'.o iL'03,30 r vi A ve 1650 1 ---- L - ,G I t ^ti► ' • ,1100° °' , ► v Il‘i 1 LO NI" LO G O V 1 °1 01 550 ��� \ / Rig: CD3 -11 s3 107L1 44 id . c,c5 m _c an Mailivig:6_ ■ I 0 , % - oti ri011. -- ■""'"Ilione p t .- -550 1 G ° lam! �' 1° / 1 2/ -1100 _ c° -2750 -2200 -1650 -1100 -550 0 550 1100 1650 West( -) /East( +) (550 ft/in) . 7�om and' ,hannbn, oee of °tseto_pratiucl " dean i:p fluids from the' eated tQ di: • You. k?a�Q tee fluids. resulting m e g o i as well as the -clears up mixing £ mud and cemet� t • a t �''lp• • oil base �cnsd • • from cleaning out the tanks , at the mud ,�1r�iit in pr5paratip�evoprt��n Q° clean up The Of the Commission had pr�riousl<Y aPrdv�l . fluids . lu ids o sal options via annular disposal at CD 1 pad. Alpine, Ca.raR 1, and Clans 2 disp Due to the geological setting. are. . re. xcdc censor, , ARCC}, had e ; t ebiisYieel LYss 1. i,mi t•ti•ort of lir7itad.. Phillips' p . ' � roved as f da s3aa?1 optii�rss. to the Corssni.sskori' g satisfaction and .annular dis�irs5al eras al? the a practical. and environmental alternative. Ist these requests the waste fluids are no different than .previously p� ,raves developuierit activ3.t.ies at Al Pine. and. Sy copy Qf • are the result of have- ngoing : • The Cbmcnf:s�ioriars. have '�itstYtar,i.�s� me to send Yo� f lue in�as described in em a: i z em*il, Phillips is authoried to dispose of 'c. .Pa your. • grail. esca,Ara4. Please call with any Tom Maunder, PE Sr. Petrcileusn Engineer AOGCC • 2 1I,P Ent Coord wrote: > Dear 14r. Maunder, epted > email, Tom Mmnson previousl requ Pent > au noted in Lk1t . di'sp os fluids s via annular. > ri± 8t , and tQ 'ant irins from' mi cingfopierla sunk. v i c.. > riissate, ann •pe rx. ine CD2 Drill Site, Mr s t8d below, > iO�CCtapp in d zilchtdisposal oa�l at the Abp and the on-site drilling integral a l relat zilch the mud t mixing facility and d n. 1999, > integral xela > operati.on- �,igYiificant. clean • P2sil.lips would Lake tci co tinui.ng p,�zs�.3ng thi request. igni . fox l • temp of rezri at the :mud mixing facility; Must occur •an•'preP' months. > temporary use of. oil based mud products at Alpine in. the coming monroutine > The a vailability of annular' disposia. a.s an option for tank. rinse fluids and The fac .litau.e this, process. > riiSesimilar wastes b x WQL gxeata there is a concern about th teemed•, however., this large settle > rinses are bent.ity of g > potential quanclty cif' fluid Chair 'c'oulc� be .g enerated durin rocess.) > clean up p• > Tanks a.:. the mud mixing fi can rt t ay contain eit hex new an6 used edt�d in > p p rinses roducts. Though rinee in cant�cc with used products mad'. be where these would > the ermiCi:ad class 1::� disposal v ��z. ` t1igPosa� well. tT�? 42 } �+ products waul is P > a di ffially be n a g i g to id c as . The cleat 1 Well is a critical all. > l delineufor maCility t h f ra content. being the. dispbaal location fa- rioritY Lo px'e'�rent . compromise to this > li.fea tic effluent, fa cility isitrasta ruoo, referred waste a to t his > d ± POtic facility. aA g Annulardisposal presents a p > disposal > alternative in this case. , . 1 • . . . . . - . • . . , . . . . . • ,.., , . . . . . . . . ( . > Thank you very Much for Your ConsideratiOn of thi4 requeSt. Please do net • - > hesitate to contaet Me or My alternate Via email or phone at (907) 670-4200 > if you have questions or need additional information. > .> Shannon Donnelly .. • > Alpine Fiel&Environmental CoordinatOr > (907) 670-4290 > ____- F by'ALP Env Coord/PPCO en. 11/92/01 •250 PK ----- . - > > . ALP Env Coord > . . . 08/31/01 1245 FM > > TO: . toitt,„MatindergadMin.stete,ak.0, . > cc: o . Silbaect: RISICIUSSt t Inject Cement RillSaC-Ca at CD2 • . > > Dear Mr. Maunder > injeCtion of cement ansate and clean-up fluids from mud and brine mixing . > operations.at the Alpine'mud plant facility into approved annular disposal .i • operations was.granted by the Alaska Oil And Gas conservation Commission > (AOGCC) in the'Merch 17,. 1999 letter from AOGCC te,DOug'Chester of ARCO > Alaska, InC., now.Phillipi Alaska, Inc, RAI). The apProValweig grant ed.0 > PAI specifiCallY. for Alpine Drill-Site CD1 arid authorized-Volumes up to > 35,000 barrels through the annular soace. > PA/ request that this approval be. extended to drilling operations at Alpine. ( > Dr xi ill Site CD2. Cement ming Opetations.fOr setting surface conduCters > will be takingplaceat the Grind .and Inject faciility which. is currently > attached to .the drilling rig at .C2. upon compleclOn of the cementing in > of the cenductore, the lines and.mixing tank will have tO be rinsed and the > rinsate disposed of. PI request approval to inject this rinsate, and > other .clean-up tram tbe mod and brine mixing operations, into the annual > spaCe of aPprovedWells located at Drill Site CD2. > ..› you have an qUestions please contact me at 670-420 > . > Tem Manson. > Alpine Field Environmental Compliance c.„:. . - Y.. torrun'aurtdenvd , . . . . . • . . . ' .. . . . • ( , . . - CD3 -122 Surface Casing Well: CD3 -122 9.625 , 40 ppf , L -80 , BTC -m casing Date: 1/15/2010 ConocoPhillips Rig: Doyon 19 Alaska. Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Pagel Top of String or Top of Flange Doyon 19 RKB to landing Ring 36.10 FMC Gen V 9 -5/8" Fluted Hanger (15 -1/4" OD) (pxp pup 2.43') 2.47 36.10 Jts 3 to 69 67 Jts 9 -5/8" 40 ppf L -80 BTC -m casing 2565.24 38.57 Halliburton 9 -5/8" "Sure Seal II" Float collar (10.67" OD) 1.24 2603.81 Jts 1 to 2 2 Jts 9 -5/8" 40 ppf L -80 BTC -m casing 77.80 2605.05 Rays Oil Tools 9 -5/8" "Silver Bullet" Float Shoe (10.67" OD) 2.20 2682.85 2685.05 2685.05 2685.05 ' 12 -1/4" TD @ 2695' MD / 2492.6' TVD 2685.05 9 -5/8" Casing Shoe @ 2685.05' MD / 2484.78' TVD 2685.05 2685.05 2685.05 75 Joints in Pipe Shed - Run 69 / Last 6 jts. out 2685.05 2685.05 One bowspring on stop 10' above shoe and on collar of jt #1. 2685.05 One bowspring on stop 10' below collar of jt #2. 2685.05 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 -67 2685.05 Total 41 Bowsprings - Two Stop Collars 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 Remarks: Average MU torque = 9500 ft Ibs Up Wt 175 K Drifted pipe w/ plastic rabbit 8.76" OD Dn Wt 145 K Used Run N Seal dope. Block Wt 74 K Supervisors: David Burley / Granville Rizek • • • . _ • - Security Level: AK Development thining, Daily Drilling Report - • ...„. CD3-122 Report Number: 5 ConocoPhillips Rig: DOYON 19 Report Date: 1/14/2010 10271110 11,115,000.00 1Wellbore Weir Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) ,CD3-122 Development FIORD NECHELIK 2.02 5.0 573.00 2,122.0 2,695.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 19,210.45 42,500.61 220,001.45 1,310,137.61 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 26.30 2.60 2/5/2010 Last casing String Next Casing OD (in) Next Casing Set Depth (ftKB) CONDUCTOR 24" Insulated, 114.OftKB Ops and Depth @ Morning Report 24hr Forecast Circ & recip 9-5/8" csg prior to cement @ 2685'. Continue to run 9-5/8" casing to 2685', circulate, cement, Rig down riser, Nipple up BOPE, test BOP equipment. Last 24hr Summary Continue to drill 12-1/4 surface hole f/ 2122' to 2695' (2492' TVD). Circulate and condition mud and hole, Backream out from 2695' to 908', blow down the top drive, monitor well-static, trip in f/ 908' to 2695', circulate bottom's up, Trip out to 169', lay down BHA #1. Clear floor. Rig up to run 9-5/8" surface casing. Pre job safety meeting. Make up Ray Oil tool 9-5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. General Remarks Weather Head Count • No Accidents / No Spills -37°, WC -68°, Wind SW @ 17 Mph, 5 mile 49.0 vis Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer :T4i Stati End OUr Time T5-S1. PH' Start Depth End T bse jirn 00:00 07:45 7.75 SURFAC DRILL DDRL P 2,122.0 2,695.0 Drill 12-1/4" surface hole f/ 2120' to 2695'. Drill w/ 10 to 25k weight on bit. Rotate 80 rpm w/ 7k ft lbs of torque on bottom, 6k off bottom . Pumping 603 gpm w/ 1310-1750 psi. Actual driling time 6.28 hrs, 5.02 rotating and 1.26 hrs sliding. PU wt 140k, SO wt 140k, Rot wt 141k. 07:45 09:00 1.25 SURFAC DRILL CIRC P 2,695.0 2,695.0 Circulate and condition mud and hole. Pumping 650 gpm w/ 1850 psi. Rotate 80 rpm w/ 6500 ft lbs of torque. Flow check- static. 09:00 12:45 3.75 SURFAC DRILL REAM P 2,695.0 908.0 Backream out of the hole from 2695' to 908' (top of HWDP). While backreaming from 2695' to 1500': Pumping 600 gpm w/ 1550 psi. Rotate 80 rpm w/ 6500 ft lbs of torque. While backreaming from 1500' to 908': Pumping 500 gpm w/ 1140 to 1100 psi. Rotate 80 rpm w/ 5000 ft lbs of torque. 12:45 13:00 0.25 SURFAC DRILL OTHR 908.0 908.0 Blow down the top drive. 13:00 13:15 0.25 SURFAC DRILL OWFF P 908.0 908.0 Flow check- static. Note: Went off hi- line at 1252 hrs, then back on highline at 1357 hrs 1/14/2010. Working to rearrange transformer f/ continued simops on CD3 pad. 13:15 14:15 1.00 SURFAC DRILL TRIP 908.0 2,695.0 Trip in the hole on elevators from 908' to 2695'. Hole in good condition. Latest BOP Test Data Date. - s Page 1/3 Report Printed: 2/11/2011 • • Security Level: AK Development ` drip Daily Drilling Report • & Wells , CD3 -122 Report Number: 5 ConocoPhitlips :j . ■ Rig: DOYON 19 Report Date: 1/14/2010 .:z�.� ©u� s n ' 3 K... s . s. 4 .E:' e . - qe S ['Tep tiE '" -0 The, 0t rs)t. _ Ptl93e . .. e p Code: c kod , �) .'1 V . tia:Code = ;_ , _T[bt 3 . v' � ��� tYperfa"flotr:= a 14:15 15:30 1.25 SURFAC DRILL CIRC P 2,695.0 2,695.0 Circulate bottom's up or hole clean. - umping 691 to 666 gpm w/ 1700 to 900 psl: Rotate 80 rpm w/ 6500 ft lbs of . orque. 15:30 17:30 2.00 SURFAC DRILL TRIP P 2,695.0 908.0 - ull. out of the hole on elevators from ►695' to 908' (top of 5" HWDP). 17:30 18:00 0.50 SURFAC DRILL TRIP P 908.0 169.0 tand back 5" HWDP f/ 908 to 169'. 18:00 19:30 1.50 SURFAC DRILL PULD . P 169.0 0.0 ay down BHA #1. 19:30 20:15 0.75 SURFAC DRILL PULD P 0.0 0.0 lean and clear rig floor. 20:15 21:45 1.50 SURFAC CASING RURD P 0.0 0.0 - ig up to run 9 -5/8" 40 ppf L -80 BTC-m urface casing. 21:45 22:15 0.50 SURFAC CASING SFTY P 0.0 0.0 - re job safety meeting on running - sing. 22:15 23:00 0.75 SURFAC CASING RNCS P 0.0 121.0 ake up Ray Oil tool 9 -5/8" eccentric hoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. 23:00 23:45 0.75 SURFAC CASING CIRC T Non -rig Other 121.0 121.0 Attempt to fill pipe and check floats using Surface Eqp Frank's fillup tool Break fill up tool from op drive. Blow down the top drive. Use team to thaw out Frank's fillup tool. ake up tool to the top drive. 23:45 00:00 0.25 SURFAC CASING CIRC P 121.0 121.0 ill three joints of casing, circulate urface to surface. Float equipment orks fine. Mud rGhecltaDafa M , ,1 g W 7 74:401:��,�`' 9 4WOM -0 t WOMZari�> U :: l taVari: t-4,104 iV e .M : g , � . - s Ge .mg e,=, d ael ti sei on �. ,44.-z-0-1,` , p pf ,DensIl3FT $ SOIrcre "L Spud 1•e=.,;� , Oe•ttx (ftK6� `''gi3 n�Qb /gait: � • .� ; *ad -� � /i� - flbfiT0ElrNk s10�lt,rr; _ �tbr4S00R'� MBT '�� ,.... -�. P � �;gf��... � „C, r Mud 2,695.0 10.00 250 23.0 42.0 38.0 79.0 88.000 27.5 9.0 9.5 Spud Mud 2,423.0 9.80 300 6.0 62.0 53.0 59.0 0.000 27.5 8.8 8.0 In ecticirl tufr - x: � ..r a aFrort tease (pbt o . en ketiNtmrti61 ..,...: tzot* m _ _- . ; Diesel 10.0 CD3 -305 MI Swaco injectivity test Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329654 Water Based Mud CD3 -122 • 280.0 CD1 -19 ASRC 329656 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329655 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329660 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329657 Water Based Mud - CD3 -122 280.0 CD1 -19 ASRC 329653 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329658 Water Based Mud CO3 -122 82.0 CD1 -19 ASRC 329659 Drip Strings:::BElA.No 'lam 8r:ABt Mtr;4 /& Bit Run Noy4 L0121t41n; kiuAhesChrtstensen MXL-[J 6t709Zr Depth In (ftKB) Out (ftKB) IADC Bit Dull String Wt (1000Ibf) 0.0 'Depth O TFA (Intl Noz) (In ") 2,695.0 I 'Nozzles (132 ") I Drill Strin. Components n z r .ks .. .._,; ` s*Y`;i1' - 1r '..i° , 1:WitenRDescrlptrol*:i:�., - ._W `° - .. --- -- :`,'.� -� e F:ti;ooltin;`. .: = - ''' [0 - ■ n - . EAU . conr SzQn) 2 ' %z0�,1004rlread ` :'-vim, . . 1 Motor with Stabilizer 8 5.000 6 5/8 H 90 1.10 1 Non -Mag Float Sub 8 2.750 6 5/8 H 90 1.10 1 $tabilizer (Non Mag) 8 3.000 6 5/8 H 90 . - 1.10 1 MWD - HCIM 8 1.920 6 5/8 H 90 1.10 1 MWD - DM 8 1.920 6 5/8 H 90 1.10 1 MWD - TM 8 1.920 6 5/8 H 90 1.10 1 UBHO (Non -Mag) _ 8 3.000 6 5/8 H 90 1.10 Page 2/3 Report Printed: 2/11/2011 • • Security Level: AK Development © p Daily Drilling Report OA/ells CD3 -122 Report Number: 5 LonocoPhitlips Rig: DOYON 19 Report Date: 1/14/2010 Drill String Components ; . .�_ -• Jut z; .�„: �_ - 71 - - _ Item Description u .. _' =�_ =, :.:. -" :- OA "pn? - °ID�Zin)�•: Toa ��To d_��: - ��l;mC ...��,� 1 Drill Collar 8 2.813 6 5/8 H 90 1.10 1 Drill Collar 8 2.813 6 5/8 H 90 1.10 1 Drilling Jars - Hydraulic 8 2.750 41/2 IF 1.10 24 HWDP 5 3.000 6 5/8 H 90 1.10 WiIibores . , ' *: * . e . -: .A, ,,. S :: t - - %� - w Welibore Name Welibore APIIUWI CD3 -122 501032060900 S e c t i o n w , . _ Y _ = Stia(in) -- - _ _ - A a t T o p J f t K B ) , , - : Act:etm x = _ : StarEDats ; - _ < , : - -EAdDate ; COND1 18 37.0 114.0 SURFAC 121 /4 114.0 2,695.0 1/12/2010 1/14/2010 INTRMI 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Survey Data -n s ms -.',. " M _ d ''f it4 _ MP ) z _ Inc/ r) -_=Azm (')- ` _ TVD (ftK8) _ VS:(it) ` , :. - HINS (tt) _ &tP- ,=:-. ,! EIN (ft) v : _ _BLS (l1OOft) 2,189.37 33.17 286.94 2,089.72 -462.73 252.73 - 433.51 2.27 2,283.30 35.05 286.63 2,167.49 - 505.23 267.94 - 483.93 2.01 2,379.66 37.79 285.97 2,245.02 - 551.08 283.98 - 538.84 2.87 2,474.74 38.60 286.09 2,319.74 - 598.05 300.22 - 595.34 0.86 2,570.05 38.21 285.12 2,394.43 - 645.09 316.15 - 652.37 0.75 2,649.05 38.23 284.82 2,456.50 - 683.59 328.77 - 699.59 0.24 I I Page 3/3 Report Printed: 2/11 /2011 I • • Security Level: AK Development '-- 'Elaillin4 Daily Drilling Report 8.Wellils_i) CD3-122 . ._ Report Number: 6 Cono ll coPhiips Rig: DOYON 19 Report Date: 1115/2010 :_q 10271110 11,115,000.00 Wellbore Well Type . Field Name DFS (days) DOL. Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 Development FIORD NECHELIK 3.02 6.0 0.00 2,695.0 2,695.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,668.51 52,169.12 469,952.51 1,780,090.12 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 27.30 1.60 2/6/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,685.1fiKB Ops and Depth @ Morning Report 24hr Forecast MU BHA #2, depth approx 733'. Pick up/ Make up/ Stand back 5" drill pipe, MU BHA #2, single in w/ 5" f/ pipe shed, test csg to 3500 psi, drill shoe track and 20' new, perform FIT to 18 ppg, drill ahead 8-3/4" intermediate Last 24hr Summary Continue to run 9-5/8" 40 ppf L-80 BTC-m casing to 1620' circulate bottom's up, continue to run casing to land on hanger w/ shoe @ 2685'. PJSM, rig down casing equipment, rig up Dowell cement head and lines, circulate and condition mud and hole f/ cement, Dowell cement 9-5/8" casing, rig displace w/ 9.9 ppg mud, bump plug w/ 58 bbls of good 10.7 ppg cement to surface. Rig down cementing and casing running tools.Lay down landing joint. PJSM, nipple down, nipple up wellhead, test metal to metal seal to 1000 psi f/ 10 minutes, PJSM, nipple up BOPE, rig up to test, test BOPE w/ 5" test joint. Witness of test waived by AOGCC inspector Jeff Jones. Pull test joint and test plug, install FMC wear bushing, rig up drilling bales and 5" drill pipe elevators, PJSM, pick up, make up/ stand back 5" drill pipe in the derrick. General Remarks Weather Head Count No Accidents / No Spills -31°, WC -53°, Wind SW © 17 Mph, 4 mile 49.0 vis Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer - ..,,,.: • -.,",,, - 4k...' , (=A- - --;0 - -- --- - -- n ,-„,',....,;;;- ,---sawn.:43 S :En .=; L e i f:,, *W-t4.'' c:;:== i - ' ---":: ----=---;-:=:=-:?!.'- :' : !DoptOsit ,oppikripttaileAw 10:11 Time, -:::(tirq. qp:priiiii .- :Awdf),C4ditqi"..k.:15•X' AitiViiii:adeVv;__PPX:= ,rs:1-ti 1:',140,50 t1;093.14 (iiiiraticeM4 00:00 02:45 2.75 SURFAC CASING RNCS P 121.0 1,620.0 Baker lock pin of joint #4, continue to run 9-5/8" 40 ppf L-80 BTC-m casing to joint # 42 (1620'). Note: Ran centralizers one per joint up to jt # 13, then every other joint. 02:45 03:15 0.50 SURFAC CASING CIRC P 1,620.0 1,620.0 Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. 03:15 04:45 1.50 SURFAC CASING 'RNCS P 1,620.0 2,685.0 Continue to run 9-5/8" 40 ppf L-80 BTC-m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Continue to install bow spring centralizers over collars to joint # 67. 04:45 05:00 0.25 SURFAC CASING SFTY _ P 2,685.0 2,685.0 Pre job safety meeting on rigging down casing tools and rigging up to cement. 05:00 05:15 0.25 SURFAC CASING RURD P 2,685.0 2,685.0 Rig down casing running equip (Frank's fillup tool) 05:15 05:30 0.25 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig up Dowell cementing head, make up 2" cementing line, I 05:30 07:15 1.75 SURFAC CEMENT CIRC P ' 2,685.0 2,685.0 Circulate and condition mud and hole f/ cement. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. FCP= 310 psi PUW 163K SOW 149K 640 bbls pumped Latest BOP Test Data Date , - , - ' - . . - =,....,_ _ ::=.4, :,,. ... .,--:. , -- . Commanti 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/4 Report Printed: 2/11/2011 1 i Security Level: AK Development Daily Drilling Report a<Vlfelts CD3 -122 Report Number: 6 ConocoPhiilips Rig: DOYON 19 Report Date: 1/1512010 -:?Stact , En[Y t ©kfi s s c 3 x� fitpne e x @YvE a O z w*: ,�'t:.�,,sPtYasa,� ���1Reod�. � �:;A�r- - E«t�'s€��e� .: �rb�Eoda�,;. �c66elass - >- .. `a�_ 07:15 07:45 0.50 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on cementing 9 -5/8" casing. While continuing to • circulate. Final mud properties 9.9 ppg, vis 60 to 70. 07:45 09 :45 2.00 SURFAC CEMENT PUCM , P 2,685.0 2,685.0 Cemented 9 5/8" rasing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. - Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10,5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 -152 psi. Observed nut plug marker at shakers wI 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbis (Class G w/ additives) ave.4.5 bpm at 110 psi. 09:45 10:15 0.50 SURFAC CEMENT DISP P 2,685.0 2,685.0 Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout Job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbis of displacement. 10:15 10:30 0.25 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on rigging down cement equipment. 10:30 11:15 0.75 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig down cementing equipment. 11:15 11:30 0.25 SURFAC DRILL PULD P 2,685.0 0.0 Back out FMC landing joint wl 10.75 4SAM2 -Left hand threads. Lay down the landing joint. 11:30 11:45 0.25 SURFAC 'DRILL PULD P 0.0 0.0 Lay down the mouse hole. Clean and clear rig floor of tools. 11:45 12:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippiing down surface riser. 12:00 13:15 1.25 SURFAC WHDBOP NUND P 0.0 0.0 Nipple down surface riser. 13:15 14:00 0.75 SURFAC WHDBOP NUND P 0.0 0.0 Remove FMC starting head. Install FMC wellhead. 14:00 14:15 0.25 SURFAC WHDBOP DHEQ P 0.0 0.0 Install FMC wellhead. Test FMC metal to metal seal to 1000 psi, hold for 10 minutes. Good test. 14:15 14:30 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippiing up BOP equipment. 14:30 16 :45 2.25 SURFAC WHDBOP . NUND P 0.0 0.0 Nipple up 13 -5/8" 5m BOP stack. 16:45 17:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on testing BOPE. Page 2/4 Report Printed: 2/11/2011 , - ---- --- • - Security Level: AK Development 11:hi Illiing Daily Drilling Report -. ,:.'- .., , . CD3-122 Report Number: 6 ConocoPhillips Rig: DOYON 19 Report Date: 1/15/2010 tiiii61:61rWart-FM PTIme.:g f. ' :.pisipll start ipetAhight i'F,M4K , lip* 1 - MAC !:=40C ni:t 37 P - Iiii*NC 1 4 - zt 6 [ !?41)c= eMtrat6iiii i Oft15:616 06 17:00 18:00 1.00 SURFAC WHDBOP BOPE P 0.0 0.0 Rig up to test BOPE. Set FMC lower test plug. Fill stack and choke manifold with water. 18:00 21:30 3.50 SURFAC WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3-1/2" x 6" variable bore), blind rams, lower pipe rams (3-1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1550 psi after operating. Recovery time test of 33 seconds for 200 psi build up and 2 minutes 55 seconds for full charge. Nitrogen bottles average 1650 psi. 21:30 21:45 0.25 1 WHDBOP OTHR P 0.0 0.0 Pull test Joint and test plug, blow down kill and choke lines. 21:45 22:00 0.25 SURFAC WHDBOP OTHR P 0.0 0.0 Install FMC long wear bushing. 22:00 22:15 0.25 SURFAC DRILL RURD P 0.0 0.0 Pickup short drilling bales, attach to the top drive. Install 5" drill pipe elevators. 22:15 22:30 0.25 SURFAC DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up and standing back 5" drillipipe. 22:30 00:00 1.50 SURFAC DRILL PULD P 0.0 0.0 Pickup/ makeup/ standback in the derrick 5" drill pipe. 8 stands picked up. modzchtickiljata:,a9jagn-W,4- 1,w ru*44 , V:g.MPEgil - T pp:04194m :*.c!3.11.1ottiks to:P01:(3PrnI '.',U4frans '. .TPRifiki =';',4W-'-*i•41:, 1 17iiiifi rpoialf rtriCilL niiiiiiiiiiiiiif iWfVeiti to1 Ili7f0:0PftlRAIRINftle' -4.46t.1600 F V. tgAt-Vir ' 1 Spud Mud 2,685.0 9.60 61 8.0 15.0 4.0 5.0 5.000 30.0 9.0 9.0 lfiJebtlbiiffufdWV flutu ,,,:=;:!;;. ,,!.--: K., -!-, , F rom LeaselbtolY Destinaffort.W:: :;! . ,;*::, - 'T , :V.!1 Manifest rtimber.:- :::-:_ww: Diesel 10.0 CD3-305 Water 40.0 CD3-305 Water Based Mud CD3-122 1335.0 CD3-305 Water Based Mud CD3-122 311.0 CD3-305 cement contaminated mud Water Based Mud CD3-122 58.0 CD3-305 cement contaminated mud Weilliciiiii',1 ixe-t Wellbore Name Wellbore APIAJWI CD3-122 501032060900 CONDI 18 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 83/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 61/8 9,140.0 15,409.0 1/25/2010 1/31/2010 . . Page 3/4 Report Printed: 2/11/2011 1 • • Security Level: AK Development �{ �nitii>cx Daily Drilling Report • CD3 -122 Report Number: 6 CariocoFhillip•s • Rig: DOYON 19 Da Report Date: ,Easfng Stdh�s- . .• �- --���� . '$fE![f��� '3icG?g'n�zz� �: ;,. � P - s i t o � �: �amrtle: - 1 x;11 n ��?CadingrTescr"�tory °=� r s., >- -- . bate E.rS, °f�k'4... ���frsHt� ,a:S(einB`ciadef:�<SeC.oe ��tKBk � , >. .. - e.: , SURFACE 1/15/2010 9 5/8 40.00 L -80 2,685.1 Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L-80 BTC-m casing to joint # 42 (1620'). Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Pre job safety meeting on rigging down casing tools and rigging up to cement. Rig down casing running equip (Frank's fillup tool/ slips). Rig up Dowell cementing head, Make up 2" cementing line. Circulate and condition mud and hole f/ cement, final mud properties: MW 9.9 ppg, vis 60 • to 70. Reciprocate and stage rate up f/ 3 bpm to 7 • bpm. Circulated 685 bbls prior to cementing. Note: Centralizers: 10' above shoe over a stop, one on collar of jt #1, 10' below float collar on jt #2, then one per joint up to jt # 13, then every other • joint to jt # 67 for a total of 41 bow centralizers and 2 stop rings, Ate. Surface Casing Cement - Started @ 1/15/2010 Type Welibore Cemented String 'Cement Evaluation Results casing 'CD3 -122 'SURFACE, 2,685.1ftKB Sty No. Description Top (ftKB) Bottom (ftKB) �Q (end) (bbl /... P (final) (psi) 1 'Sur Casing Cement 36.0 2,685.0 4 490.0 __s-lf ' gg e A' it sack :' i4 Esti (ftKBf =r "= € Est BLm tea` - _ - _ :i`Si' ::�OUnF Sack$ -�" � "4`.�S,Xe`.�. {7(1r ., .�ng:4 sdekWl � ��la `:34a�N Id( Elo�d ' _ -,- � :'Crass- , �->r ( f «.'. Viscosifled Water 35.0 8.40 MudPush 11 50.0 10.50 ArcticSet Lite 360 293.0 10.70 4.57 36.1 Alpine Surf TaII 140 50.0 15.80 1.17 2,185.0 2,685.0 • • Page 4/4 Report Printed: 2/11/2011 410 .. . .._ :Emi f Cement Detail Report , ...,.... • i.: • &Wells .', CD3 -122 ConocoPhillips y String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 CemetltRetails ,Z n .z -��;'g : Yt- _ nZf . *° as . =fni.g:M n - ti';g.i _ F : Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/15/2010 07:45 1/15/2010 10:15 CD3 - 122 Comment Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH 11 spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbls of displacement. Cement Stages -_ - . a Z Z Z` F = % - Stage #'F: Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 2,685.0 Yes 58.0 Yes Yes Q (start) (bbilmin) Q (end) (bbl /min) Q (avg) (bbilmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 4 5 490.0 1,050.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) 8 3/4 Comment Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Cement Fluid & Additive e - � 't - `� � . - V `,- Fluid x. * �.t= ' iA- -gi3x� --, W s P 5 _t •, - `ate _ ; _ �` a 3 _ �.ra Fluid Type _ A Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water 35.0 Yield (f "Isack) Mix H2O Ratio (gallsa... Free Water ( %) Density (113/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Ftuttt ;:x.. _ _ t i -. f _ , - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush 11 50.0 Yield (ft'lsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid `, : r • - �,� . _ N .• -_ .,;' , E. • � . ' -i _ u ^ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) ArcticSet Lite 36.1 360 293.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.57 21.23 10.70 1 Additives Additive Type Concentration Conc Unit label S001 Accelarator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 antifoam 0.6 %BWOC Additive Type Concentration Conc Unit label D079 extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 extender 50.0 %BWOC Additive Type Concentration Conc Unit label D044 Freeze suppressant 9.0 %BWOW Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Page 1/2 Report Printed: 2/11 /2011 1 ZL Cement Detail Report CD3 -122 ConocoPhiliips Et.. String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10 /201013:00 Cement Fiuid & Addittves � � � �' � �`• . ��_. � : - f y. ?.. r. - ...�...., a:. :a.e... :air :, y.�... •s -',�. 'yam' . ^ ' . ^ z� .• - '`.'�': _ ._�- n�"-'"� > ?,�:x:3 . _.»+.'. ..':"� " fix {': i. ..a.•.:.� . ....:^ .x> >.:. � �� ��'•�. z.�� _'+� H;. :'sib_: - -. :`�;�:i ^`�`:: �[ . "x?x';. �'K -.. ..�•"C �+.:. -+t-e. :a _R.E:_�. _:'iki:s -�,. �. :Fluid ....,.._,,.. _. �:;,- �•�:.� :_ �3: � :r :..� >� 't��%�;'s?.i�'3�.�E°�+. -�• . . �^:�'�.` -.., ... ssr.sza, :��... � ".�. _ ..r .... .z Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surf Tail 2,185.0 2,685.0 140 50,0 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label S001 Acceiarator 1.0 %BWOC Additive Typo Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC • • • Page 2/2 Report Printed: 2/11 /2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -122 Rig: Doyon 19 (Date: 1 1/16/2010 I Volume Input Volume /Stroke Pump Rate: Drilling Supervisor: 1) t3uHey/ G =Z:zeK Pump used #2 Mud Pump Strokes 1r 0.1000 Bbls /strk V 7.00 strk/min ■ Type of Test: Casing Shoe Test LOT /FIT ■ Pumping down annulus and DP. V Casing Test Pressure Integrity Test Hole Size: 8 -3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 33.6IFt 2685.01Ft -MD1 2484.0IFt -TVD 2715.01Ft -MD I2508.0IFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC v 0 70 0 3630 0 10 0.00 1060 Casing Test Pressure IntegrityTesl 2 180 1 3630 1 40 0.25 870 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 4 320 2 3630 2 90 0.50 750 • ` f Mud 10 min Gel: 40.0 Lb /100 Ft2 Mud 10 min Gel: 40.0 Lb /100 Ft2 6 540 8 760 3 3630 3 180 1.00 700 Test Pressure: 3500.0 psi Rotating Weight: $1444#14/4 Il Lbs 4 3620 4 280 1.50 680 Rotating Weight: Lbs Blocks /Top Drive Weight: 75000.0 Lbs 10 910 5 3620 5 400 2.00 660 Blocks /Top Drive Weight 75000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1070 6 3620 6 500 2.50 660 ■ � 16 1470 8 3620 8 670 3.50 640 Estimates for Test: 2.4 bbls Estimates for Test: 1085 psi 0.7 bbls 14 1280 7 3620 7 590 3.00 650 EMW = Leak-off Pressure +Mud Weight = 7U ! n 15 Second 18 1660 9 3610 9 740 4.00 640 0.052 x TVD 0.052 2484 Shut Pressure, psi 20 1860 10 3610 10 820 4.50 630 EMW at 2685 F t -MD (2484 Ft-TVD) 16.3 870 _ - 22 2090 15 3610 11 870 5.00 630 4000 - - Lost 30 psi during test, held - 24 2330 20 3600 12 900 5.50 620 - 99.2% of test pressure. = 26 2590 25 3600 13 940 6.00 620 �.1 - • 3500. - 28 2830 30 3600 14 990 6.50 610 - 30 3100 15 1030 7.00 3000 - - 32 3370 16 1070 7.50 600 34 3630 17 1100 8.00 600 - - 8.50 600 W 2500 - 9.00 600 0 2 2000 __ 9.50 590 w 10.00 590 C+: 1500 ..." 1000 f 1 500 - - 0 o 1 2 3 a o s ,o 15 20 25 30 Volume Volume Volume Volume Barrels Shut -In time, Minutes wortr CASING TEST .13•• TEST O PIT Point Pumped Bled Back Pumped Bled Back 3.4 Bbls �Bbls 1.7 Bbls �Bbls ` Comments: LUJ -tLL our usy ri 1 nnai.xis Summary PRESSURE INTEGRITY TEST ® t '3 CONOCOPHILLIPS A Iaa _- Well Name: CD3 -122 Rig:l Little Red Date: 2/28/2011 Volume Input Pump Rate: Drilling Supervisor: ____1_ _ Browning 1 (Pump used: 10ther See Comments V Barrels ■ Bbls /Strk ♦ 0.75 Bbl /min lir Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ♦ _ _ Casinj Test _ Pressure Integrity Test Hole Size: 18-3/4" • Casing Shoe Depth I Hole Depth Pumping Shut - in Pumping Shut - in RKB -CHF: 34.2 Ft 2801.0 Ft -MD -238476' Ft -TVD 4172.0IFt -MD 13656.0iFt -TVD _ Bbls psi Min psi Bbls psi Min psi Casing Size and Description: USE PICK LIST V 0 0.5 460 0.00 1050 Changes for Annular Ad Test ' Pressure IntegritvTest 1 1 625 0.25 950 Enter outer casing shoe test results in comments Mud Weight: 6.8 ppg 2 1.5 925 0.50 950 _asing description references outer casing string. Inner casing OD: 7.0 In. 3 2 950 1.00 950 Hole Size is that drilled below outer casing. 4 2.5 975 1.50 950 Use estimated TOC for Hole Depth. 5 3 1050 2.00 940 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3.5 1075 2.50 940 Estimates for Test: 1017 psi -0.4 bbls 7 4 1075 3.00 925 v 8 4.5 1075 3.50 925 EMW = Leak -off Pressure + Mud Weight = 975 It PIT 15 Second 9 5 1075 4.00 925 0.052 x TVD 0.052 x + 6.8 Shut -in Pressure, psi 1 5.5 1075 4.50 925 EMW at 2801 Ft -MD (2384 Ft -TVD) = d 4C3 p , 950 15 5.00 925 I 6.00 9 25 1500 20 5.50 9 �. 25 M 30 6.50 8 EV - MIIIMINIIMIN 7.00 910 =III - - - C MII---E ln/ 7.50 910 _ .111101M11111 8.00 910 �000 M %� 8.50 910 w r' - 9.00 910 or iii - r ' ►'���1�Z: 1 0.00 910 w MEW 1111111.1111111a cc a_ NMI IMMWMIEE 500 WWI 111111111 MEM 0 2 3 4 5 6 0 5 • 15 25 so Volume Volume Volume Volume Barrels Shut -In time, Minutes *'CASING TEST -F -LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls I Bbls 5.5 Bbls I Bbls Comments: Initial OA Pressure 460 Psi - Tested w/ 3/4 BPM Coristant w/ LRS Unit - Sled Pressure Baclk to 500 Psi and Shut In . _ CD3 -122 liifet-ilvliy T 02_28_201 l.xla Summary PRESSURE INTEGRITY TEST /....0 lit 1 CONOCOPHILLIPS AI- -, - Well Name: CD3 -122 Rig: Doyon 19 Date: ' 1/23/2010 A Volume Input 1 Pump Rate: Drilling Supervisor: 1 I Fred Herbert / Granville Rizek 'Pump used: Cement Unit Barrels ■ Bbls /strk W 0.80 Bbl /min ■ I - Type of Test: Annulus Leak Off Test for Disposal Adequacy V Pumping down annulus. ■ j _ Casing Test Pressure Integrity Test Hole Size: 8 -3/4" v Casing Shoe Depth 7 Hole Depth Pumping Shut -in Pumping Shut -in RKB - CHF:1 34.2 2801.OjFt - MDR 2484.01Ft - TVD 4172 IFt -MD 13656.0IFt -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC V 0 0 39 0.00 599 Changes for Annular Adequacy Test Pressure IntegritvTest 1 0.5 144 0.25 547 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 247 0.50 542 . asing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 349 1.00 539 H ole Size is that drilled below outer casing. 4 2 437 1.50 537 Use estimated TOC for Hole Depth. 5 2.5 516 2.00 '5 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 579 2.50 531 Estimates for Test: 672 psi 0.3 bbls 71 3.51 633 3.00 530 v 1 v 8 3.75 648 3.50 529 - - -- - -- - - 4 622 4.00 528 EMW = Leak-off Pressure + Mud Weight = 579 + 9 8 PIT 15 Second 0.052 x TVD 0.052 x 2484 Shut -in Pressure, psi 10 4.5 617 4.50 527 EMW at 2801 Ft -MD (2484 Ft -TVD) = 14.3 547 15 51 613 5.00 526 woo - - - - 20 5.5 602 5.50 525 ma 25 6 602 6.00 524 /� ` -'" ' 30 6.5 602 6.50 524 7 599 7.00 523 4 7.50 521 8.00 9 20 w 3 /_a_, _ 8.50 ,20 c ., ■ ■ ■ ■ 1 9.00 519 4 500 518 51 7 w 0 i a 1 . . • a 1 1 . ' i 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Volume Volume Volume Volume Barrels Shut -In time, Minutes •CASING TEST -♦LEAK-OFF TEST O PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls IBbls 7.0 Bbls IBbls Comments: Surface Casing FIT @ 18.1 PPG EMW - - 7" Casing Shoe @ 9130' MD (6958' TVD) CD3 -122 OA LOT 01 -23 -10 .xI Summary • • CD3 -122 Intermediate Well: CD3 -122 7" 26 ppf L -80 BTC -m Casing Date: 1/22/2010 ConocoPhillips Rig: Doyon Rig 19 Alaska. Inc Depth Jt Number Joints Well Equipment Description and Comments po i Length Tops Page 1 ........... T op of String or Top of Flange ...... • RKB to Casing Flange (Load shoulder 34.53') (LLDS 33.61) 33.61 FMC 7" Mandrel hanger 1.29 33.61 7 ", 26 #, L -80, BTC -m Casing Pup jt Pin x Pin 1.27 34.90 Jts 98 to 224 127 Jts 7 ", 26 #, L -80, BTC-m Casing 5156.50 36.17 HES 7" Stage Collar 2.43 5192.67 Jts 4 to 97 94 Jts 7 ", 26 #, L -80, BTC -m Casing 3802.83 5195.10 ✓ HES Shut -off Baffle Collar 1.01 8997.93 Jts 3 to 3 1 Jts 7 ", 26 #, L -80, BTC -m Casing 43.44 8998.94 HES Sure Seal II Float Collar w/ By -Pass Baffle Adapter 1.00 9042.38 Jts 1 to 2 2 Jts 7 ", 26 #, L -80, BTC -m Casing 84.52 9043.38 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 9127.90 9130.02 8 -3/4" Hole TD A 9140' MD / 6958.9 ' TVD, Hole angle 86.28 deg 9130.02 7" Shoe A 9130.02' MD / 6958.3' TVD/ Hole angle 86.28 deg 9130.02 9130.02 Total of 91 Straight Blade centralizers (7" x 8 -3/8 ") - 5 Stop Collars 9130.02 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 9130.02 r 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 9130.02 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 9130.02 1 Straight Blade centralizer per jt on jts # 4 - #30 floating 9130.02 9130.02 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. #97 9130.02 1 Staight Blade centralizer w/ stop 10' Stage Collar -Jt. #98 9130.02 1 Straight Blade centralizer per joint floating # 99 thru #123 9130.02 9130.02 1 on 3 jts Across Shoe jts # 159, #160 & 161 9130.02 then 1 every other jt # 163 to # 223 9130.02 9130.02 9130.02 9130.02 9130.02 Planned: 230 jts in pipe shed / 224 jts to run. 9130.02 6 joints left in the shed 9130.02 9130.02 9130.02 Remarks: Drifted w/ 6.17" plastic rabbit Up Wt 285 K Average MU torque= 8000 Ft Ibs Dn Wt 180 K Block Wt 74 K Supervisors: Fred Herbert/ Granville Rizek • . Security Level: AK Development .,..Drilling_. Daily Drilling Report &Wiens CD3-122 . , Report Number: 13 ConocoPhi II ips Rig: DOYON 19 Report Date: 1/22/2010 - s1" , ==4AW1 -- ,Yi=:,e - X-NAFE:17 , Y15E , SMM- -- -MM - AvIt *.,"_,NisdivotiviD i 10271110 11,115,000.00 Weltbore Well Type 'Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) 'Depth End (ftKB) CD3 Development FIORD NECHELIK 10.02 13.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost rally Cost Total Cumulative Cost 5,375.22 310,814.69 769,563.22 4,064,324,69 Actual Start Date Original Spud Date AFE our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 25.79 3.11 2/5/2010 Last Casing String Next Casing OD (In) Next Casing Set Depth (ftKB) INTERMEDIATE, 9,130.0ftKB Ops and Depth @Morning Report 24hr Forecast i Changing top pipe rams to 3 x 7". Circulate, cement through stage collar, R/D cementing and casing tools, pull wear bushing, install packoff, test packoff, change upper pipe rams, lay down 5" DP, PU 4" DP, test BOPE. Last 24hr Summary Change top pipe rams to 7", PJSM, RU, test to 250 psi and 3500 psi, R/D test equip, install FMC thin wear bushing, PJSM, RU, PJSM, Run 7" csg: MU fist 4 jts, fill pipe w/ Frank's fillup tool, circ 20 bbls, check floats- OK. Con't to run 7". Avg MU torque 8000 ft lbs. The first 30 joints have Ray Oil Tool 7" x 8-3/8" Aluminum straight blade centralizers. Con't to run 7" csg f/ 1200' to 2630'. Circ & cond mud @ 2630'. Con't to run 7" f/ 2630' to 5065'. Between jt # 97 and # 98 is the Halliburton Type HES 7" stage collar (Baker locked). Centralizer floating on Jt # 97 & # 98 between a stop, 10' above and below cementer. Circ & cond mud @ 5065'. Con't to run 7" f/ 5065' to 7507'. Centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. Circ & cond mud @ 7507'. Con't to run 7" f/ 7507' to 9130'. PU wt 300k, SO wt 175k. R/D Frank's FU tool. RU Dowell cement head & cementing hose. Circ a total of 693 bbls, PJSM. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls © 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll, Shut down, load bottom plug. Pump another 5 bbls of mudPushll @ 11.5 ppg. Shut down, load shut off plug. Mix & pump 56.7 bbls 15.8 ppg(273 sx) (1.16 cuft/sx) 5.076 gal/sx) cement @ 5.2 bpm avg w/ 400 psi initial and 140 psi final. Drop Halliburton shut off plug, chase w/ 20 bbls water pumping 5.3 bpm w/ 44 psi initial and -17 psi final pressure. Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Recip until 15.8 bbls before bumping plug, final rate 3 bpm, landed on FMC hanger. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1-22-2010. Landed on hanger 2336 hrs 1-22-2010. Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. General Remarks Weather Head Count No Accidents / No Spills -24°, Wind E @ 14 Mph, 10 mile vis 51.0 - 4-1-1: , • - •: -- ::::=:,. - -4 Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor • Dave Egedahl, Rig Engineer Rig Engineer -- - ,=. .r., Tie Log -....,-.•il:5,?,-----v----, 'ntl:"i'-'ill'INEWEakit*-1"1:;Si -iA-",-rtt4,i*AVIVRR.,7*7-n-, 510 ''-tireci::''::: , :-0-'101 F aijt W. fo'0060 lkcetVititiiag; :;e4A,: , ':r:Iii)i:ei;a4t: : egia':=: ::4MAIS-1 i-f-AfttOM 4 00:00 00:30 0.50 INTRMI WHDBOP NUND P 0.0 0.0 Continue to change upper pipe rams (3-1/2" x 6") to 7". Blind rams are closed. 00:30 00:45 0.25 INTRMI WHDBOP BOPE P 0.0 0.0 Pre job safety meeting on rigging up to test 7" rams. 00:45 01:00 0.25 INTRMI WHDBOP BOPE P 0.0 0.0 Rig up to test 7" rams. 01:00 01:15 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Test 7" upper pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. 01:15 01:30: 0.25 INTRMI WHDBOP BOPE P 0.0 0.0 Blow down testing lines. Rig down. 01:30 02:00 0.50 INTRM1 CASING PULD P 0.0 0.0 Install FMC thin wear bushing (10.75" ID). Lay down the 7" test joint. 02:00 02:15 0.25 INTRMI CASING SFTY P 0.0 0.0 PJSM on rigging up casing running equipment. 02:15 02:45 0.50 INTRMI CASING RURD P 0.0 0.0 Rig up to run 7" 26 ppf L-80 BTC-m casing. 02:45 03:00 0.25 INTRMI CASING SFTY P 0.0 0.0 PJSM on running 7" 26 ppf L-80 BTC-m casing. Latest BOP Test Data Date - =:-- - , - :: : t - , - : "' - :- 2,': - . - : - . =: - : - si:: - .4:00: - -:',; - : , - :=:'------, - •f• - i.ki.:4tn , i: - .4,Ccupinentv:.0 - x - , -- :::: - i' , ..'k - -Ki - -V' - ,‘--=; - , - ..,:, - -; . ft.o.:;ik: -- ,7, ,, . - .,: - :: 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/5 Report Printed: 2/11/2011 • • Security Level: AK Development Daily Drilling Report &Wells CD3 -122 CanotoPhill € Report Number: 13 ps Rig: DOYON 19 Report Date: 1/22/2010 Start ?EMS rxuf's 3y - -., i ;` ^ : e " =: ` is �ifoe c > ; 'ice. x 0 O t th Stark ` - QepttndkE: :: 1me 1 fm 4brsp ` 1 plies 4:01 ,,e &> Worn j.;E ' a h = TrbrCode � � s ?d�Pga e � MO , s peaktrii 03:00 04:00 1.00 INTRM1 CASING RNCS P 0.0 172.0 Run 7" casing: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock Joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full Joint. Four connections were bakerlocked. 04:00 04:15 0.25 INTRMI CASING CIRC P 172.0 172.0 Fill pipe w/ Frank's fillup tool, circulate 20 bbls, check floats- OK. 04:15 06:00 1.75 INTRMI CASING RNCS P 172.0 1,200.0 Continue to run 7" 26 ppf L -80 BTCM casing. Average make up torque 8000 ft Ibs of torque. 30 jts in the hole. The first 30 joints all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. 06:00 07:30 1.50 INTRMI CASING RNCS P 1,200.0 2,630.0 Continue to run 7" 26 ppf L -80 BTCM casing from 1200' to 2630' (Jt # 30 to jt # 65). 07:30 08:15 0.75 INTRM1 CASING CIRC P 2,630.0 2,630.0 Circulate and condition mud © 2630', prior to exiting surface casing shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. 08:15 11:00 2.75 INTRMI CASING - RNCS P 2,630.0 5,065.0 Continue to run 7" 26 ppf L-80 BTCM casing from 2630' to 5065' (Jt # 65 to jt r . ;r # 125). PU wt 193k, SO wt 150k. Between Joint # 97 and # 98 is the 7" Halliburton Type HES cement stage tool. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box • and the box. A centralizer floating between the pin and 10' above the pin of joint # 98. Then centralizers were installed floating on jt # 99 to # 123. 11:00 12:00 1.00 INTRMI CASING CIRC P 5,065.0 5,065.0 Circulate and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. 12 :00 15:00 3.00 INTRMI CASING RNCS P 5,065.0 7,507.0 Continue to run 7" 26 ppf L -80 BTCM casing from 5065' to 7507' (Jt # 125 to it # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. 15:00 16:30 1.50 INTRMI CASING CIRC P 7,507.0 7,507.0 Circulate and condition mud Q 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. Page 2/5 Report Printed: 2/11 /2011 • - - Security Level: AK Development Daily Drilling Report &Wells CD3-122 Report Number: 13 C.onocoPhillips Rig: DOYON 19 Report Date: 1/22/2010 Thrtiri:L.2 7 1/4 - : - - 5 - 001:01:Elici ='rhne ;: Wiktfaitird4 Itawattiwopviarifeer*g, 16:30 19:00 2.50 INTRMI CASING RNCS P 7,507.0 9,130.0 Continue to run 7" 26 ppf L-80 BTCM casing from 7507' to 9130' ( Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K PU wt to break over. Landed on hanger @ 1900 hrs. 19:00 19:15 0.25 INTRM1 CASING RURD P 9,130.0 9,130.0 Rig down Frank's fill up tool, blow down the top drive. 19:15 19:30 0.25 INTRMI CEMENT RURD P 9,130.0 9,130.0 Rig up Dowell cement head and cementing hose. 19:30 21:45 2.25 INTRMI CEMENT CIRC P 9,130.0 9,130.0 Circulate, staging pumps f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. Pre job safety meeting while circulating. Circulated a total of 693 bbls. Final mud properties : PVNP= 9/16. MW 9.8 ppg 21:45 22:30 0.75 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial to 190 psi final. Shut down, then load bottom plug. Pump another 5 bbls of 11.5 ppg mudPushll. Shut down and load shut off plug. 22:30' 22:45 0.25 INTRMI CEMENT PUCM P 9,130.0 9,130.0 Dowell mix and pump 56.7 bbls (273 sx) Alpine tail cement (15.8 ppg) (1.16 cuft/sx yield) (5.076 gal/sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 400 psi initial and 140 psi final pressure. Drop Halliburton shut off t plug, chase w/ 20 bbl of water, pumping 4.5 to 5.3 bpm w/ 44 psi to -17 psi. 22:45 23:45 1.00 INTRMI CEMENT DISP 9,130.0 9,130.0 Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Reciprocated f/ 9130' to 9120' until 15.8 bbls before bumping plug, landed on FMC hanger. Slowed to 3 bpm for the last 20 bbls pumped. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1-22-2010. Landed on hanger 2336 hrs 1-22-2010. 23:45 00:00 0.25 INTRMI CEMENT OTHR p 9,130.0 9,130.0 Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. In eatinn'.'Finicl;-<-":4' FluId e- • Diesel 35.0 CD3-305 Water Based Mud CD3-122 40.0 CD3-305 Wellbore Name Welibore API/UWI CD3-122 501032060900 WOW CoN D1 18 37.0 114.0 Page 315 Report Printed: 2/11/2011 • • III Security Level: AK Development ...;-$•;:_. ,, •,- • -,--, .q niiiiing,,, Daily Drilling Report &We Ills CD3-122 Report Number: 13 ConocoPhil I ips 7 Rig: DOYON 19 Report Date: 1/22/2010 .:=„i, I 4:W- (IrCZW:44W.04: LAikft'Acr:700 40 SURFAC ' 121/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 83/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 CiiftifrSfiffiaiI.na4tMn : ;,:g :: :-,7-,, ' - -Zi4.f: . W10:Strtngti:r4Rpriiviimp* - ~vg4. - :,:e.01..4,_. ,... :4,' :,:':.: V:: : i* ,:,:-.;..„. it ?WIWI 41:01:istrriiadrado 4*a:ft AtitEM ikw*=-:‘ .s.An INTERMEDIATE 1/22/2010 7 26.00 L-80 9,130.0 PJSM on running 7" 26 ppf L-80 BTC-m csg. Run • • 7" cg: Pick up jt #1: Ray 011 tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8-3/8") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal 11 Float Collar w/ baffle adapter Installed. Baker lock pin of Jt #4 with centralizer floating the full joint. 4 jts w/ baker ■■ lock. Fill pipe w/ Frank's FU tool, circ 20 bbls, 4 ,1. check floats- OK. Con't to run 7" 26 ppf L-80 BTCM csg. Avg make up torque 8000 ft lbs. The toilk first 30 jts all have Ray Oil Tool 7" x 8-3/8" Aluminum straight blade centralizers. Con't to run ,j 7" csg from 1200' to 2630' ( Jt # 30 to jt # 65). Circ t r and condition mud @ 2630', prior to exiting surface • csg shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k,. SO wt 124k. Con't to run 7" csg from 2630' to 5065' ( Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the Halliburton Type HES 7" stage collar. Ray Oil tool straight blade 7" x 8-3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and • the box. A centralizer floating between the pin and 10' above the pin of jt # 98. Then centralizers 7 installed floating on jt # 99 to # 123. Circ and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. Con't to run 7" csg from 5065' to 7507' ( Jt # 125 to jt # 185). PU wt 260k, SO wt • 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163 to # 223. Circulate and condition mud fg 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. pu wt 253k, SO wt 185k. Con't to run 7" 26 ppf L-80 BTCM casing from 7507' to 9130' ( Jt # 185 to jt # 124 + FMC hanger and landing joint). KJ wt 300k, SO wt 175k. Required 315K to break over. Landed on hanger @I 1900 hrs. Quit recip 2336 hrs 1/22/2010 during cement job. Final PU 285k, SO - 180K. • • 0iiiiiiiht •:' .:,'-::::-: :'.›;..:::r..:;:: Intermediate Casing Cement - Started (121 1/22/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3-122 INTERMEDIATE, 9,130.0ftKB Stg No. Description Top (MB) Bottom (ftKB) Q (end) (bb1/... P (final) (psi) - . 1 Intermediate Casing Cement • 7,786.0 9,140.0 3 410..0 :•'? '''''Z'Vgle11$11MV-Air70414lirflbigakArfigrdirtsackr4 MW.tati k-VMMEst Stilt tftgaMilt dii■i (), 40.0 8.40 • 5,652.0 6,719.0 MudPush 11 40.0 11.50 6,719.0 7,786.0 Page 4/5 Report Printed: 2/11/2011 1 0 Security Level: AK Development �'I:kill ng : Daily Drilling Report &Wells >% CD3 -122 Car,ocoi ?hlnips Report Number: 13 Rig: DOYON 19 Report Date: 1/22/2010 : Fluid - .- _' Class -- Amount (sacks) V (bbd- , ` -. Density-Old/gait:- =- - :Yield (fflsack) _ - - .- _ Est-Top (ftKB)' - - _ -_ • °. Est Btm (1KKB) ° -- Alpine Intermediate Tail 273 56.7 15.80 1.16 7,786.0 9,140.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl!... P (final) (psi) • 2 Intermediate Casing Cement 4,167.0 5,193.0 2 270.0 .- >,z " Fluid _,.Class ;`-- Amounr(sacks) V(bbl) _ �_ ' cleosity:(tb!9alX _ = Yieid:(fersuo10: € = :Est?Top:(ftKB) - -v`° - - Est Win(ftl(13)-. CW100 30.1 8.40 2,500.0 3,303.7 MudPush 11 31.6 11.50 3,303.7 4,146.7 Alpine Surface Tail 187 39.2 15.80 1.17 4,146.7 5,192.7 1 Page 515 Report Printed: 2/11 /2011 r _ 0 • Security Level: AK Development Milling Daily Drilling Report ---- ,:. &Wens CD3-122 Report Number: 14 ConocoPhillips -.. Rig: DOYON 19 Report Date: 1/23/2010 "AFE-TYPe::::::1:4--aMgs:e :=1:'-AW*....:' -s..far.,.:1: , 10271110 11,115,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-122 Development FIORD NECHELIK 11.02 14.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,708.41 314,523.10 222,713.41 4,287,038.10 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) jJob Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 26.79 2.11 I 2/6/2010 Last casing String 'Next Casing OD (In) Next Casing Set Depth (ftKB) INTERMEDIATE, 9,130.0ftKB Ops and Depth @ Morning Report 24hr Forecast PU/MU/RIH w/ 4" Dp w/ BHA #3, depth approx 5000 • PU/MU BHA #3 to dean out cement in 7", RIH, test csg to 1000 psi above stage collar, drillout stage collar, test to 1000 psi, con't to PU/MU/RIH w/ 4" dp, test to 3500 psi above baffle collar, drill cement to 9120', circ, POOH f/ BHA #4, PU/MU/RIH w/ BHA Last 24hr Summary Estab circ thru Halliburton 7" HES stage tool at 5192.67'. Pump 6 bpm w/ 270 psi. PJSM on 2nd stage cement job while circ 6 bpm w/ 250 psi final. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls © 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll © 5.2 bpm w/ 262 psi initial - 220 psi final. Shut down. Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 ppg) (1.17 cufVsx yield) (5.105 gal/sx water) (5.34 hrs thickening time). Pump 5.2 bpm average w/ 260 psi initial -150 psi final pressure. Drop Halliburton closing plug, chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displace cement w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final, bumped plug at calculated strokes (1779 strokes). Pressure to 1100 psi, bled off pressure, tool not shut. Re-pressure to 1500 psi, tool shut at 1425 psi. Bumped plug © 0209 hrs 1-23-2010. Held pressure 4 minutes, bled off pressure. R/D cement head and hose. UD 7" landing joint. PU/ MU wear ring pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. UD running tool. Torque lockdown screws to 450 ft lbs. Test 7" packoff to 5000 psi for 10 min. L/D 7" csg equip. PJSM,change top pipe rams to 3-1/2" x 6, change saver sub to 4" XT 39. PJSM, RU to test, Test BOPE: Everything to 250 psi low, annular to 2500 psi high, all other components to 3500 psi high, chart all tests. Hold each test 5 minutes. Tested accumulator. Witness of test waived by AOGCC inspector Chuck Scheve. Tested BOPE w/ 3-1/2", 4", and 4-1/2" test joint. Pull 4-1/2" test joint and test plug, blow down kill and choke lines, blow choke manifold, install FMC (7-1/8" ID) wear bushing, PJSM, Pick up/ stand back 4" drill pipe in the derrick, via the mousehole. General Remarks Weather Head Count No Accidents / No Spills. Rig off highline @ 1300 hrs, back on @ 1415 hrs. Moved cable to -7°, Wind SW © 8 Mph, 10 mile vis 50.0 the rig. ,, E , --:..k..,.: - Fred Herbert, ▪ Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor A Dave Egedahl, Rig Engineer Rig Engineer :'..:-.--..14-.%-l Tirtle;;Og;:- ,;?::: , soctr.: ',Enct 'ktit.r5 =ja.=:,-,.„ : :: 4.•g4W Wik:ge.:7_-4*'' :-Ma '0001tOttMaietAttlgK3_ 1, llenii,' 'lline ', - iiIiisk i,:: 1007c 7Abootoodeg itiCic' 7 =F3. 41(filOM -- 4 - VOSOM W-4err:**I7Orti 6 ,> 00:00 00:30 0.50 INTRMI CEMENT CIRC P 9,130.0 9,130.0 Establish circulation through the Halliburton 7" HES stage tool at 5192.67'. Pumping 6 bpm w/ 270 psi. I 00:30 00:45 0.25 INTRM1 CEMENT SFTY P 9,130.0 9,130.0 Pre job safety meeting on 2nd stage cement job while continuing to circulate. 00:45 01:00 0.25 INTRMI CEMENT CIRC P 9,130.0 9,130.0 Circulate, pumping 6 bpm w/ 250 psi final. Circulated a total of 332 bbls. No indication of CW100 or mud push at the shakers. 01:00 01:15 025 INTRMI CEMENT PUCM P 9,130.0 9,130.0 Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls © 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll © 5.2 bpm w/ 262 psi initial and 220 psi final. Shut down. Latest BOP Test Data 1/23/2010 Witness of test waived bv AOGCC inspector Chuck Scheve. Page 1/4 Report Printed: 2/11/2011 • 0 • • Security Level: AK Development Daily Drilling Report a. ens ... WV _ . . . . . CD3-122 Report Number: 14 conocophit I ips ' -/ • 1 • Rig: DOYON 19 Report Date: 1/23/2010 tiiiVetift*WW.V*Var,~411MROMMV-Vall-AR 'N•Stai it_' f :41?4r,4 i XVIVAN'T:..kik i..,04,:w.f..; NV.1444414W.: 15.1gme:: PePttYStertArki0 r•:!-.: " ..: FkrWi jUtiria" Wireptia;511:4i mitiaage. trIbt 00'8;11 MOM tAit!Malirl :444wat :, ,: ,:;-:::-?' 01:15 01:30 0.25 INTRMI CEMENT PUCM P 9,130.0 9,130.0 Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 it t■ ppg)(1.17 cuft/sx yield) (5.105 gal/sx water) (5.34 hrs thickening time). Pump V at 5.2 bpm average w/ 260 psl Initial and 150 psi final pressure. Drop Halliburton closing plug, then chase w/ 20 bbl of • water, pumping 5.2 bpm w/70 psi. 01:30 02:15 0.75 INTRMI CEMENT DISP P 9,130.0 9,130.0 Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm w/ 140 psi Initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi Initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final prior to bumping plug at calculated strokes (1779 strokes). Pressured to 1100 psl, bled off pressure, tool not shut. Re-presure to 1500 psi, tool shut at 1425 psi. • Bumped plug @ 0209 hrs 1-23-2010. Held pressure 4 minutes, bled off pressure. 02:15 03:30 1.25 INTRMI CEMENT RURD P 9,130.0 0.0 Rig down cement head and hose. Lay down 7" landing joint. 03:30 04:15 0.75 INTRMI DRILL OTHR P 0.0 0.0 Pick up/ make up wear rig pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. Lay • down the running tool. Torque the lower Iockdown screws to 450 ft Ibs of torque. 04:15 04:30 0.25 INTRMI DRILL PRTS P 0.0 0.0 Test the 7" packoff to 5000 psi for 10 minutes. Witness of test by FMC Bobby - and Rig Supervisor. 04:30 05:00 0.50 INTRMI DRILL PULD P ' 0.0 0.0 Lay down 7" casing equipment. 05:00 05:15 0.25 INTRMI WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on changing top pipe rams from 7" to 3-1P2" x 6" variables. 05:15 06:30 1.25 INTRMI WHDBOP NUND P 0.0 0.0 With blinds shut. Change upper pipe rams to 3-1/2" x 6" variables. Also changing saver sub on the top drive from • 4-1/2" IF to 4" XT 39 06:30 06:45 0.25 INTRMI DRILL SFTY P 0.0 0.0 Pre Job safety meeting on rig up to lay • down 5" drill pipe f/ derrick. 06:45 07:15 0.50 INTRMI DRILL RURD P 0.0 0.0 Install drilling bales �n the top drive. Install 5" elevators. _ . . 07:15 12:30 5,25 INTRMI DRILL PULD P 0.0 0.0 Lay down 5" drill pipe from the derrick via - the mouse hole. A total of 59 stands were layed down, leaving 30 stands of 5" • in the derrick for the next hole. - . 12:30 13:00 0.50 INTRMI bRILL PULD P 0.0 0.0 Lay down 5" drilling tools, pick up 4" drilling tools. . . _ . 13:00 13:15 0.25 INTRMI DRILL SFTY P 0.0 . OA/ Pre job safety meeting on moving hi-line - cable to the rig. . . Page 2/4 Report Printed: ' 2/11/2011 1 • Security Level: AK Development nrinin Daily Drilling Report & w e n s • - CD3-122 Report Number: 14 C.onocoPhillips . Rig: DOYON 19 Report Date: 1/23/2010 • = ,-z,§tom Perpurs3.00 tl?!9) Encti Zffri*A4..r41 •=4;iativity kt 13:15 13:45 0.50 INTRM1 DRILL RURD P 0.0 0.0 Rig went off hi-line at 1300 hrs, back on at 1415 hrs. Disconnect Hi-line cable, re-route cable due to construction activities on pad. 13:45 14:00 0.25 INTRMI DRILL SFTY P 0.0 0.0 Pre job safety meeting on slip and cut drilling line. 14:00 15:15 1.25 INTRMI RIGMNT SVRG P 0.0 0.0 Hang blocks. Slip and cut 60 of 1-3/8" drilling line. Service the top drive. 15:15 15:45 0.50 INTRMI RIGMNT SVRG P Change the 5" die blocks on the iron roughneck to 4". Adjust air pressure on the top drive. 15:45 17:15 1.50 INTRMI WHDBOP RURD P 0.0 0.0 Set FMC upper test plug. Rig up to test BOPE. 17:15 22:30 5.25 INTRMI WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Rig electrician tested floor methane alarm and pit H2S alarm- good. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3-1/2" x 6" variable bore), blind rams, lower pipe rams (3-1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 3-1/2", 4" and 4-1/2" test joint. Accumulator test performed: initial pressure 3000 psi, 1650 psi after operating. Recovery time test of 34 seconds for 200 psi build up and 2 minutes 43 seconds for full charge. Nitrogen bottles average 1675 psi. 22:30 23:00 0.50 INTRMI WHDBOP OTHR p 0.0 0.0 Remove FMC upper test plug. Blow down kill and choke lines, blow down • chioke manifold. Set FMC 7-1/8" ID wear bushing. 23:00 23:15 0,25 INTRMI DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up and standing back in the derrick 10 stands of 4" drill pipe. 23:15 00:00 0.75 INTRM1 DRILL PULD P 0.0 0.0 Pick up/ make up/ stand back 4" drill pipe in the derrick, via the mouse hole. Note: Performed injectivity test, flush and freeze protected 9-5/8" x7" annulus on CD3-122 with dowel! on 1-23-2010. Injectivity test 7 bbls 9.8 ppg mud, 300 bbls water, 50 bbls diesel. Mud Check Data 'SOkle, Corr :400116011Z g(11419.0Pr - -!:(0#41-PSW '-C LSND 9,140.0 9.80 35 9.0 17.0 6.0 8.0 - 10.000 140.2 9.6 10:0 w/Inhibycol Page 3/4 Report Printed: 2/11/2011 • • Security Level: AK Development Daily Drilling Report CD3 -122 Report Number: 14 ConocaPhillips • Rig: DOYON 19 Report Date: 1/23/2010 I njectton=FfntMM ' § x qc fluid` - ,.. Sow.,., it Lit ateqpbir Destrnadbrr: w z , ,s_:s. Vendor,_ ;r, x=, rMatffestNurtidry , :=; t z; oNWse: ~: g:: '-"; Diesel 50.0 CD3 -122 Freeze protect 9 -5/8" x 7" Diesel 25.0 CD3 -305 • Pit Rinsate CD3 -122 217.0 CD3 -305 ASRC 334751 Water 300.0 CD3 -122 Flush 9 -5/8" x 7" Water 150.0 CD3 -305 Water Based Mud CD3 -122 1214.0 CD3 -305 Water Based Mud CD3 -122 280.0 CD3 -305 ASRC 334753 Water Based Mud CD3 -122 220.0 CD3 -305 ASRC 334752 Water Based Mud CD3 -122 7.0 CD3 -122 Initial injectivity 9 -5/8" x 7" MAO :,.�..:.• rte^ N Wellbore Name Welibore APIIUW1 CD3 -122 501032060900 . x :.,€,.,..: :�r>Slze.i .,€ fir.. <:�.z a,._.. fAct. .. ° :..,.AcE'B (ftKe} _,. fQat -�:.., .,:.. - -.. .. _.- CONDI 18 37.0 114.0 SURFAC 121 /4 114.0 2,695.0 1/12/2010 1/14/2010 INTRMI 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 - PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 sea _";.> a-3i - z: ..,' ' _ t ' . " ° .. - - ±`° • Via.: - Z, _ -;'�`� _ v:; °<tffi:6..� `.ry.:� "Y =te . ��.; .•��.'.. '., s# �;.a <'. � •. Leak.Oif.atad€:Fbrrnatton'►t�e r es��,��:.�:�:�'�: �... �� '�= �:�.�:� �� =�_,:- Leet :...a a :�FDeFIsF1.' -='";:a' "Y .: =�x si��`�f� , v . Yes INTERMEDIATE, 9,130.0ftKB 4,172.0 9.80 Water 648.0 13.21 2,509.3 • • • • Page 4/4 Report Printed: 2/11 /2011 • • ,Di ling ,< Cement Detail Report ' &Wells ', CD3 -122 ConocoPhitlips . String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 CementDetall$ - 1 P _ 1 M: I Description Cementing Start Date Cementing End Date Welibore Name Intermediate Casing Cement 1/22/2010 21:50 1/23/2010 02:15 CD3 -122 Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbis. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushll. Shut down and load shut off plug. Dowell mix and pump 56.7 bbis Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbls before bumping plug. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on FMC hanger @ 2336 hrs 1 -22 -2010. Held press 4 min, bled off press -floats held. Load Halliburton closing plug f/ 2nd stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Circ a total of 332 bbls. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbis @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbis (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump @ 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush @ stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi Initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 Ceriieilt- Stage$ �a`v 'rte - M _ _ . -'t.� -A,1- 1: >* s - - a '--.. *- �f mil` a' _Stage'# 1` -- -_ <___ ____ - M ..._gg*kage ._ _�r. �._ v;: > „_ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Cement 7" intermediate 7,786.0 9,140.0 Yes 0.0 Yes Yes Cement 1 Q (start) (bbl /min) !Q (end) (bbl /min) Q (avg) (bbl /min) rP (final) (psi) P (bump) (psi) IRecip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 6 1 410.0 930.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushli. Shut down and load shut off plug. Dowell mix and pump 56.7 bbls Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbis before bumping plug. PU wt 280 to 285k, SO wt 180k. , Bumped plug @ 2341 hrs 1 -22 -2010. Landed on FMC hanger @ 2336 hrs 1 -22 -2010. Held press 4 min, bled off press -floats held. Load Halliburton closing plug f/ 2nd stage. ,, Cement Flufds &- Add itives-. .0 _ I i, >ta ra . � - - "- Fluid `° 4 . _�.._- ftt_a_, =- i iM aVl;- ti s _, _ .. -. . _. -a Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 5,652.0 6,719.0 40.0 Yield (ft'lsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive `Type !Concentration Conc Unit label Fluid - * � r; 1 E ' _ £ . _.. - _ t _ - <I ' Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 6,719.0 7,786.0 40.0 Yield (ft'/sack) Mix H2O Ratio (gai/sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive (Type Concentration Conc Unit label Fluid � ' - .:. ,= _ , - .£. _:ticw..4 _ A .. _ w> Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Intermediate 7,786.0 9,140.0 273 56.7 Tail Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Page 1/2 Report Printed: 2/11 /201 - • • „, - aE�rrltr lr Cement Detail Report `. &Welts CD3 -122 CanotoPhillips °' String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 • Additives -. Additive Type Concentration Conc Unit label D046 anifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 disperssant 0.3 %BWOC - s ::3: °a- z;=?' =• >_ `,3'k =- 3.'E? ..O- d :r ?.'''=-".x<Y. .'s:ei ` 4 ,- "<;: r - . �.� :.a. �� ate: ..'''�wfir v :sue u. .. r..: r ,�.. C`ement.Sta es;:�`.,.„ -<� �; - .�= �::. >_. �� �' =��4. _.,: -- Jena- '� 2 " - - 3: 9`3 -ai e �` x = a4 ks..., s-a' Y C. <"im. 3 r .°.a St` age; #Z_: .ter �,�k,,.. ,.=.v°" ,.d�-� 4.> .. ...f : . � �r�.�� s°.a��'�z'"'.r .�...,3�"��`"�_�?:s < - Description Objective Top (ftKB) Bottom (ftKB) �� Full Return? Cmnt Rtm (... Top Plug? Btm Plug? intermediate Casing Isolate Quannik 4,167.0 5,193.0 Yes Yes No Cement formation Q (start) (bbl /min) Q (end) (bbl/min) Q (avg) (bbUmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 2 6 270.0 1,425.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Load Halliburton closing plug f/ 2nd stage after checking floats on first stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Clrc a total of 332 bbis. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and•pump 31.6 bbis 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbis (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump @ 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush @ stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 . - .. -.,,.. t _ -,.a '434 7 '' - f_S 'V.�L � �} W. 6emeatiElafds &0.dditiire `� _ .. . =4 < Fiura._ . h'u�'�z.�'�= �.';'���� v ��.� ` ., � ��- <°.�3�� .. W�.:� � �-� NR, -, :� Wxm�'3= ��e�'�� ::, Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumpe (bbl) CW100 2,500.0 3,303.7 30.1 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water ( %) Density (tb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive (Type 'Concentration (Conc Unit label Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 3,303.7 4,146.7 31.6 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives 4" Additive jType Concentration ent IC one Unit label My:- Y ca 'z<.: 1**-4V -. r ,� -'V : ffiz> ,: "'s`ad ;4 -.:.�r -,-x •,.z�' Fli,id r :�� ���� -�aK m���s�a� ��= ����:'�`�:�:°.`Y��»��f���_ �� � -_ �� � �_. _ .�7��4� �r - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surface Tail 4,146.7 5,192.7 187 39.2 Yield.(fY /sack) Mix H2O Ratio (gaUsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psl) 1.17 5.10 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label 0046 anti foam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 dispperssant 0.3 %BWOC Page 2/2 Report Printed: 2/11 /2011 PRESSURE INTEGRITY TEST 4vr Utz CONOCOPHILLIPS Ala , Well Name: CD3 -122 Rig: (Date: 1/27/2011 1 olume Input Pump Rate: Drilling Superviso Don Mickey Pump used: Other - See Comments Barrels 0.7500 Bbls/Strk Mr 0.75 Bbl /min Type of Test: 1 Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ■ Casing Test g Pressure Integrity Test Hole Size: 8 - 3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: IFt 2801.0IFt -M] 2384.0L -TVD 4172.0IFt -MD 13656.0IFt -TVD _ Bbls psi Min psi Bbls psi Min psi Casing Size and Description: USE PICK LIST ' V 0 0 500 0.00 1000 Changes for Annular Adequacy Tes Pressure IntegrityTes1 1 0.5 550 0.25 950 Enter outer casing shoe test results in comments Mud Weight: 6.9 ppg 2 1 650 0.50 925 Casing description references outer casing string Inner casing OD 7.0 In. 3 1.5 680 1.00 925 Hole Size is that drilled below outer casing. 4 2 775 1.50 925 Use estimated TOC for Hole Depth 5 2.5 850 2.00 900 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 950 2.50 900 Estimates for Test_ 100 psi -0.4 bbls 7 3.5 1050 3.00 900 vi V 8 4 1050 3.50 900 EMW = Leak -off Pressure + Mud Weight = 1050 + 6 9 PIT 15 Second - 9 4.5 1050 4.00 900 0.052 x TVD 0.052 x 2384 Shut -in Pressure, psi 10 5 1200 4.50 900 EMW at 2801 Ft -MD (2384 Ft -TVD) = 15.4 950 15 5.5 1200 5.00 900 1500 - - 20 6 1190 5.50 - - 25 6.5 117' 6.00 C /4,3 30 7 1175 6.50 _ / 7.5 1175 7.00 7.50 8.00 Li j 1000 • 0 8.50 �r 9.00 ir . I LOT 9.50 w 10.00 a 500 a- Z$ .- /( 0 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume �ntrisCASING TEST •LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls IBbls 7.5 Bbls IBbls Comments: Injectivity test with Little Red Pumped @ .5 bbls /min for 4.5 bbls - increased to .75 bbls /min for last 3 bbls pumper I..UJ 1 LL 'Annuldr LU I - U I .L / . I I .xis Summary, • • CD3 -123 Information Pack .t, • �� �� �� Casing Detail Well: cD3-123 9-5/8"40 ppf L-80 BTC-m Casing Date: 4/4/2010 Rig: UA` �K�s � �i Dnyun19 Alaska Inc Depth Jt Number Joints VVeUEquipma,uDeschpdonund Commen Length Tops pagn1 ;����;�;: �;�;�;�;�;�; ~` ��m� � ������ �� ���. .. Top of String or Top of Flange Doyon 19 RKB to top of landing Ring 3010 FMC Gen V 9-5/8" Fluted Hanger (15-1/4" [}D\ .22 30.10 9'5/8" 40 ppf L-80 BTC-m casing pup P x P 2.18 36.32 Jts 3 to 73 71 Jts 9-5/8"40 ppfL-80 BTC-m casing 2715.06 38.50 Halliburton 9-5/8° "Sure Seal II" Float collar (fC[70~OD) 1.20 2753.56 Jts 1 to 2 2 Jts 9-5/8" 40 ppf L-80 BT{}-nn casing 76.32 2754.76 Rays Oil Tools 8-5/8^ "Silver Bullet" Float Shoe /YO.70''OD) 2.29 2831.08 2833.37 Bottom mfshoe >>> 2833.37 2833.37 12-1/4" TD @ 2843' K8C}/2467`TVO 283337 9-5/8" Casing Shoe @ 2833' K8D/24G8'TVD 2833.37 2833.37 2833.37 77 Joints in Pipe Shed - Run 73 / Last 4 jts. out 2833.37 2833.37 One bowspring on stop 10' above shoe and on collar ofjt #1. 2833.37 One bowspring on stop 10 below collar of jt #2. 2833.37 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 -71 2833.37 Total 43 Bowsprings - Two Stop Collars 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 2833.37 Remarks. Up Wt 107K DnWt 145K Block Wt 75 K Supervisors: Burley / Browning • Security Level: AK Development Daily Drilling Report &Wells_ CD3-123 Report Number: 4 conocaPhillips Rig: DOYON 19 Report Date: 414/2010 10278811 1 • 9,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-123 Development FIORD NECHELIK 2.50 4.0 39.00 2,804.0 2,843.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,036.54 39,168.55 200,302.54 1,003,391.55 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/1/2010 4/2/2010 27.01 25.19 1.82 4/26/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,833.0ftKB Ops and Depth @ Morning Report 24hr Forecast N/D Riser © 0515 Cement Casing - N/D Riser - N/U & Test BOPE - P/U 5" DP Last 24hr Summary Continued to Drill 12 1/4" Hole t/ 2,843' MD (TD) - Circulate Bottoms Up X 2 - Back Ream t/ 907' MD - Observe Well For Flow (Static) - Trip in Hole, Worked Though hard Spot @ 1,153' MD and Minor Tight Spots @ 2,215' and 2,308' MD - Ream f/ 2,804' to 2,843' MD - Circ & Condition Mud - Trip Out-of-Hole on Elevators t/ 907 MD - Observe Well for Flow (Static) - UD BHA #1 - R/U and Run 9 5/8" Casing t/ 2,833' MD - Circulate and Condition Mud Prior to Cementing General Remarks Weather Head Count No Accidents - No Spills-Running one engine w/ Hi-line. -15, Freezing Fog, Wind Calm 49.0 - - : Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer iTInrikLcig - tart End DUr - Time - - - - - :DeetttStart, 1-31iTik! A - :="r- ,- -TrbrCtiae gegg,P,Mft-- 00:00 01:00 1.00 SURFAC DRILL DDRL p 2,804.0 2,843.0 Drilling f/ 2,804' to 2843' MD - 2,468' TVD ADT 0.57 ART 0.18 hr AST 0.39 hr PUW 149 SOW 127 Rot Wt, 136 Torque On/Off 7.5 / 5 550 GPM @ 1500/1350 Psi On/Off WOB 15-30 01:00 02:00 1.00 SURFAC DRILL CIRC P 2,843.0 2,709.0 Circulate and condition mud - 600 gpm / 1830 psi / 60 rpm @ 5H ft/Ibs Stood back two stands to 2709' 02:00 05:45 3.75 SURFAC DRILL TRIP p 2,709.0 907.0 Performed wiper trip to 907 - Back reamed from 2,709' to 907 - 600 gpm / 1650 psi / 60 rpm - slowed pump rate to 500 gpm from 1500' md - no problems - flow check well, static 05:45 07:00 1,25 SURFAC DRILL ' REAM p 907.0 1,187.0 RIH from 907' - unable to pass 1151' - made several attempts to pass tight spot with out pumps - no good. Attempted to rotate passed tight spot with low pump (5 bpm) motor stalling - Increased pump rate to 450 gpm and oriented motor to high side - drilled past tight spot 1151' to 1154' - worked bit passed tight spot several times - hole conditions improved. Large volume of fine sand and chunks of compressed wood (coal) circulated out across shakers. Shut down pump and slid bit 1, past tight spot - OK. Reamed stand down to 1187' - appeared to be cleaning out more sand. 07:00 08:15 1.25 SURFAC DRILL TRIP P 1,187.0 2,804.0 RIH from 1,187' to 2,804 - minor tight spots @ 2215' and 2308' Latest BOP Test Data Page 1/3 Report Printed: 2/11/2011 • Security Level: AK Development Daily Drilling Report -•. CD3-123 Report Number: 4 ConocoPhillips Rig: DOYON 19 Report Date: 4/4/2010 time Log Start- Efld:1 --Du! - Depth Star Dept!) Endi; Tun Time (hrs) Phase Op Code ,,- ActNitiCede frbl Class. (ftKB) , -AftKB):7'., Mtg" 08:15 09:45 1.50 SURFAC DRILL CIRC P 2,804.0 2,804.0 Establish circulation - Precautionary ream from 2,804' to 2,843' - Staged pumps up to 600 gpm / 1830 psi / 60 rpm - Circulate and condition mud - increased MW from 9.8 ppg to 10.0 ppg - maintained high viscosity and added fluid loss materials - observed large amount of sand and cutting through first BU - shakers quite clean after second BU - set back one stand - Blow down top drive - Flow check well - static 09:45 12:45 3.00 SURFAC DRILL TRIP P 2,804.0 170.0 POOH on elevators from 2,804' to 907' - no problems - Flow check well, static - Continue to POOH on elevators - stand back HWDP - Hole appears in good shape 12:45 14:45 2.00' SURFAC DRILL PULD p 170.0 0.0 POOH - Laid down remainder of BHA components - Clear tools from floor - clean up trip mess 14:45 16:15 1.50 SURFAC CASING RURD P 0.0 0.0 Rig up to run 95/8" casing 16:15 16:30 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Pre job safety and Ops meeting with crew 16:30 19:45 3.25 SURFAC CASING RNCS p 0.0 1,614.0 Run 95/8" Casing per Detail t/ 1,614' MD (42 Joints) P/U 137, S/O 110 19:45 20:15 0.50 SURFAC CASING CIRC P 1,614.0 1,614.0 CBU @ 5 BPM w/ 250 Psi 20:15 22:00 1.75 SURFAC CASING RNCS p 1,614.0 2,833.0 Run 9 5/8" Casing t/ 2,794' MD (31 Joints) - M/U Landing Joint and Land Casing w/ tail @ 2,833' MD P/U 185, S/O 135 22:00 22:30 0.50 SURFAC CASING RURD 2,833.0 2,833.0 R/D Casing Running Equipment & R/U Cement Head 22:30 00:00 1.50 SURFAC CASING CIRC 2,833.0 2,833.0 Ciro & Condition Mud Staging Pumps Up f/ 3 © 240 Psi to 7 BPM (g 350 Psi Prior to Cementing MidCh�kData- , Gel (199) ponsity Teglp ESolidd; Gpfr; Dens 4.14e/O1)-- !:::Pbf11001t *,:(1k1/10Pfr) :?-:= Ntbf110011 140- glifel0,40C4 Spud Mud 2,843.0 10.00 300 17.0 77.0 69.0 72.0 0.000 27.5 9.0 8.5 Spud Mud 2,843.0 10.00 300 20.0 105.0 80.0 98.0 148.000 27.5 9.0 8.0 Spud Mud 2,843.0 9.80 300 14.0 91.0 71.0 86.0 88.000 27.5 9.0 8.0 rojectiOPTIOid Aquid - . Q.0/eridor Diesel CD3-123 30.0 CD3-304 Diesel CD3-123 8.0 CD3-304 Drilling Mud WBM CD3-123 280.0 CD1-19 ASRC 329637 Drilling Mud WBM CD3-123 275.0 CD1-19 ASRC 329638 Drilling Mud WBM CD3-123 153.0 C123-304 Water CD3-123 150.0 CD3-304 DriltStringe:' BHA 1 -:E57 Motor 4I5-5.3 Stage Bit Run -=:.:121WEltighettiriiMXIAXA0711 Depth in (ftKB) Depth Out (ftKB) TFA (Inc! Noz) (In') Nozzles (132") • IADC Bit Dull - String Wt (1000Ibf) 0.0 2,843.0 0.75 18/16/16/12 2-1-BT-M-E-3-HC-TD Page 2/3 Report Printed: 2/11/2011 0 0 Security Level: AK Development Daily Drilling Report etWel111.5 ... CD3-123 Report Number: 4 ConocoPHillips 1? 1 Rig: DOYON 19 Report Date: 41412010 Drill String Components : ilts - -,==- : = _.----- = - item Description::: - : : , OD (in) = .ii!' '-'. - ''_' Top Conn Sz (in) ' . ffoFf - 3tIread s --- ". 1 8" Sperry ABI Motor 8 5.000 6 5/8 H-90 32.94 1 Integral Blade Stabilizer 7.98 3.000 6 5/8 H-90 39.59 1 8" EM Drill Collar 8 1.920 65/8 REG 62.16 1 NM Index Sub 8 1.920 6 5/8 REG 65.26 1 Mm Antenna Sub 8 1.920 65/8 REG 68.36 1 NM Crossover/ Float Sub 7.88 2.810 65/8 H-90 70.79 1 NM UBHO Sub . 7.8 3.063 6 5/8 H-90 73.19 1 NM Flex Drill Collar 7. 2.813 65/8 H-90 103.24 1 NM Flex Drill Collar 7.73 2.813 65/8 H-90 134.09 1 7.75 DNT Jars 7 3/4 2.750 4 1/2 IF 168.71 5" Drilipipe to surface - 5 4.276 4 1/2 IF 907.13 24 24 x 5" HWDP 5 3.000 4 1/2 IF 907.13 brining Parameters .. --.-- - ::: : : -, ==- ,- ,: , A4',.7.q•= . :7, - f!:' = ', - :::- : _WIC : ::::::::: - :'!4_`; -- - ':'&-, - --;' - gA : r4f,=:::::::11 : r. : _q!' : = - F , I1:::Z , .:' ,= ;:.. -- FIow-Rate ...„.„ - . . : ,,.. _ - - -_. .... -. .- - :. 2,?.: - Z si kro iniii=', , _- - -.::ilks 'eft IiAz :Mt - ,, , iii,i. ! 0,.:, - &-Ft_.*:---vk Start (ftiii3). :Eid (fRB) Cum ri;iitri ?OkiiiiiiiinTiiiiiiii (hrs) Time (10) ' :: :*68(l0f) rtritor , . - --,:?-81P iiii'.:': !,==(10001P.Cf2 r:Z.(1999 .': 40ftiiiiii1'4 r ..;;Z:Zfr Drill :rq 2,804.0 2,843.0 2,843.00 21.30 0.39 550 30.0 60 1,500.0 149 136 - 127 5.0 7.5 Well .=..-::-.: ''''''• ial;'.3.= Welibore Name Wellbore APIAJWI CO3-123 501032061700 Section -: - : - , :-- =--= - i - _ - .. Size tiny i = ii : i i; .: =. .-= ,-=,Act Top (KS) -_-=----------'-' ,-- --==:-. i= Act Bbn (SKB) -,=4ii;==:=4 ,:1 . - =..-.-:-.- J ,= i, ..ii== V End Date : - :' , '_ - 4 , ..- - , - ,; - _ - ,=== - CONDI 19 36.0 114. SURFAC 12 1/4 36.0 2,843.0 4/2/2010 4/4/2010 INTRMI 83/4 2,843.0 11,053.0 4/6/2010 4/9/2010 PROD1 61/8 11,053.0 17,142.0 4/15/2010 4/20/2010 Casing Strings ;-:: : ,-„, ..-, :. -1-:.:„*:.:--E-e.._, - ,- .. ,,,g- c - .- - -.:i: :. 1:,: - :7En.' . .z.:..] 44,,,-....VA,..:-,04:4:-.F4.::•-i,,-.-..:,.-,,-,=3;;--,-;:-::&:-.I::„ ,_:-..4.,..-,::;„5:11.:,a,--,-.,-, i- ,--:-; --. ---:-: =i '': :-. ".: ',. -,, ' ' E ORO '4.'Mr100 Wt ;' := 4 Vila: - - , i:n - - , .. - ki - -5 --. --5 - -:*4:4-A - . Casing Description i ==:--. - :==:1,. - := - V.' - 4-==!V= , Ran Date i :: 7:1-„ii.:'"=: iililb,S#03 Stang Giadd :::::: Depth (f013):0.- = SURFACE 4/4/2010 9 5/8 40.00 L-80 • 2,833.0 Page 3/3 Report Printed: 2/11/2011 • Security Level: AK Development Irining Daily Drilling Report CD3-123 Report Number: 5 C.onocoPhillips Rig: DOYON 19 Report Date: 4/5/2010 s Network/ID 10278811 9,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-123 Development FIORD NECHELIK 3.50 5.0 0.00 2,843.0 2,843.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,000,02 48,168.57 462,090.02 1,465,481.57 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/1/2010 4/2/2010 27.01 26.19 0.82 4/27/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,833.OftKB Ops and Depth @ Morning Report 24hr Forecast Testing Surface Casing t/ 3500 Psi P/U BHA - RIH - Test Casing - Drill Float Equipment - FIT - Drill Formation Last 24hr Summary Continue to Circulate and Condition Mud Prior to Cementing - Cement Surface Casing - N/D the Riser - Install Wellhead and Test t/ 1,000 Psi f/ 10 Minutes - N/U BOPE R/U and Test BOPE w/ 5" Test Jt; Test Witnessed by AOGCC Inspector Bob Noble - P/U 5" DP - Slip & Cut Drill Line - Begin P/U BHA #2 General Remarks Weather Head Count No Accidents - No Spills-Running one engine w/ Hi-line. -9, Fog, Wind Calm 49.0 Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer fi ,End Dur - ;Arne- =Depth itaii ,pepthin:a YrirrP.:- Time : (hrs): I Ph856■ 7'1Nita& Actiity Code ?-11-x 00:00 01:00 1,00 SURFAC CASING CIRC P 2,833.0 2,833.0 Circ & Condition Mud Prior to Cementing -7 BPM @ 340 Psi 01:00 03:15 2.25 SURFAC CASING CMNT P 2,833.0 2,833.0 PJSM - Pumped 51 Blois of 10.0 PPG Mud w/ Nut Plug Marker, then 34 Bbls of Biozan/Nut Plug Pill w/ Rig Pumps @ 5 BPM w/ 280 Psi - Dowell Pumped 3 Bbls of Water - Pressure Tested Surface Lines t/ 3,500 Psi - Dropped the Bottom Plug and Pumped 50 Bbls Mud Push II, 321 Bbls of 10.7 PPG Class G Lead Cement and 50 Bbls of 15,8 PPG Tail Cement @ an Average of 7.5 BPM w/ 421 Psi - Dropped the Top Plug, Then Pumped 20 Bbls of Fresh Water - Rig Pumps Displaced the Cement w/ 188.5 Bbls of 10.0 PPG Mud @ 500 Psi - Bumped Plugs @ 1885 Strokes - Held 1100 psi on the Floats for 5 Minutes - Released Pressure Checked Floats (Good) - CIP @ 0315 hrs - 42 Bbls of Cement Returned to Surface 03:15 04:30 1.25' SURFAC CASING RURD P 2,833,0 2,833.0 R/D Cementing Equipment While Monitoring Cement Level in Annulus - Dropped — 7' (1 Bbl) in 45 Minutes 04:30 06:15 1.75 SURFAC WHDBOP NUND P 2,833.0 2,833.0 N/D Surface Riser & Remove Slip Lock , Assembly 06:15 07:30 1.25 SURFAC WHDBOP NUND p 2,833.0 2,833.0 install Well Head & Test t/ 1,000 Psi f/ 10 Minutes 07:30 09:15 1.75 SURFAC WHDBOP NUND p 2,833.0 2,833.0 N/U BOPE - Change Swivel Packing 09:15 10:15 1.00 SURFAC WHDBOP RURD p 2,833.0 2,833.0 R/U to Test BOPE Latest BOP Test Data Date s Comment 4/5/2010 Witnessed by Bob Noble, AOGCC Page 1/2 Report Printed: 2111/2011 0 4110 Security Level: AK Development 11:14111014 Daily Drilling Report . _.. CD3-123 Report Number: 5 .T. Conor.oPhillips :•== Rig: DOYON 19 Report Date: 4/5/2010 Time Lo .-:'-:.==.-::::;:t]:::1= : Sot. -,:- End , , ,Dur: i: : ;_-:„:: , - -!:•, : :-. : .. - -grinie :-'4 ii---7:: , 5!4f , zy:4-igi: ChTill7Blef,t :Pe. , Erifo: $::::.„ ;:-::::!: - --: ............................ z.1 Time lime : - (firO) f , •: -9 ::: -- Flfie s eiT - Mr: '',1 -k.,...T:a.k.616J-b :?=',:_:;=fii ::;5. MOug3M, 'j-f(fIKB) -' :-W:'::::'_ 10:15 14:00 3.75 SURFAC WFIDBOP BOPE P 2,833.0 2,833.0 Test BOPE w/ 5" Test Joint - Test Annular Preventer t/ 250/2500 Psi - Test All Choke Manifold valves, 4" DEMCO, Upper and Lower Pipe Rams & Blind Rams t/ 250/3500 Psi - Test Gas Alarms, Flow Alarms, PVT Alarm, and Perform Accumulator Draw Down Test - Test Witnessed by AOGCC Inspector Bob Noble 14:00 14:45 0.75 SURFAC DRILL RURD P 2,833.0 0.0 Set Wear Ring & R/U to P/U 5" DP 14:45 21:30 6.75 SURFAC DRILL PULD P 0.0 0.0 P/U 5' DP f/ the Pipe Shed via the Mouse Hole (69 Stands) 21:30 23:00 1.50 SURFAC RIGMNT SLPC P 0.0 0.0 Slip & Cut 60' of Drill Line - Service Top Drive 23:00 00:00 1.00 SURFAC DRILL PULD ID 0.0 82.0 P/U BHA #2 per DD t/ 82 MD m _.,-: ; !,,:,.s, !,:.::-,H- ; ;- : ,,, , ,nz,!;= ; :3- ; .--. : ,:.: :: :_ , :;_.;,.,.-.:,-,--;,;,-.; ; f.E_L.1,;:i,.: : , i i., .-..,::: .,-,.:-.!: f;-, A;M:504A;:!:';:::::ttM4-- _..'',',=-: YP Calc .,Gel AWAY,: ::: Peliillea);,' ;',,Gef ppm) - :;. :::.,:e.,-::::NALT t-4, itatisity T9FIR 1§91108, Corr:: f!grTYpiii-':=":]: Depth (ftKB)- Denslibigalj Vie WA 'FiV6alo lop)' :'-,:labfilOgfe):7- - _ - .(10V100fr) ;-: ;.::(eg71f30fel '-'-- :, =:(114/190fe):?-i: - ii113T(jEll,b()7.:4043941.10)::11 4Y:::: :-T--,afF)::?l- :'a-, - Spud Mud 2,843.0 9.65 40 8.0 11.0 4.0 4.0 5.000 175.3 - 9.0 8.0 trifiCtiOliFlUid.'H -._ - - - -' -:- -=:-:'-_- .:-.:: ::":-: -. ::, Fluid ,. : - : - --,. 1 ,- -. Source. =.: , From Lease (bbl) :---::: -Destination - . - -. -:-:: Vendor:,_,=,:,::- -- -. - lManifest Number:-', ::&: ];',: „.-$: ::: :,:-,:.:.-._- :-:-- Cement Rinsate CD3-123 142.0 CD3-304 Diesel CD3-123 30.0 CD3-304 Freeze Protect Diesel CD3-123 5.0 CD3-304 Injectivity Test Drilling Mud WBM CD3-123 739.0 CD3-304 Drilling Mud WBM CD3-123 630.0 CD3-304 Drilling Mud WBM CD3-123 172.0 CD3-304 Other CD3-123 563.0 CD3-304 Cement Contaminated Mud Water CD3-123 150.0 CD3-304 Flush Water CD3-123 150.0 CD3-304 Flush Water CD3-123 20.0 CD3-304 Flush Water CD3-123 20.0 CD3-304 Flush Water CD3-123 20.0 CD3-304 Flush Weltb eretc:::::: - - :-.--..:. ,- - , t,:::;: - =.=z-_-.:e-,=,;:.=,::=- - -::-:-:- - i,:==zr--,-.--. -, ::;., !::::::K:f , _:.-:-.s..,===:'::::=7; - :=:,, , ,,?..-:=., , ;=. : :;- - ,p - ,=,-,=:: - ,=:==.,: - ..,:,A, ,- „,57.-,_=: , -...-!--, , A:f . :=.,'. - :'z - -,11-?--=- - -: - &:rsgF- - =-:,m - Welibore Name Wellbore API/UWI CD3-123 501032061700 -- Section- - - : ., - .,.,. : - ::Size(le):: . --_ZAct-Top :: - --- - Act BIM (ftIKB)::: - -; ,, ,: , ,: - Startl:late -- ::-::' - : - -::-:' ,- -=.:-'::; -, i - ;:'i - '] , :; , ; - =,Eild:Date --::::--_:: ::.:': CONDI 19 36.0 114.0 SURFAC 12 1/4 36.0 2,843.0 4/2/2010 4/4/2010 INTRM1 83/4 2,843.0 11,053.0 4/6/2010 4/9/2010 PROD1 6 1/8 11,053.0 17,142.0 4/15/2010 4/20/2010 C emen t : :=:=W:1-:=Tp-2 - ='=',=_:- -- , - *-';: , : , .. - - - 4 , ==iiiii=aktiN=5.:::::.4=]:==.:-.7;-=7-1 - ,E - -t-=.*:: : ::-.nq;;I: - :i2.-:=2.=_, , : , :: Surface Casing Cement - Started A 4/5/2010 Type Welibore Cemented String Cement Evaluation Results . casing CD3 SURFACE, 2,833.OftKB .. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) ibb1/... P (final) (psi) 1 Surface Casing Cement 36.0 . 2,834.0 4 500.0 -: :--== - -- - : fluid : :--.,..:::,.--- :,---, .].: Class :::::-.,:- -:-Amount (secics)-: : (WI) , : ,.- _- Density (Ib/gel) . E., -- Ylelcilft * Isack): ] .: 2.:,'.: -_-- .EstTop (ftKB) .::::,--,:-:-: :::1-; :='], !PIMP): :".,:.: -::-,, Lead Cement G 400 321.0 10.70 4.52 36.0 2,343.0 Tail Cement G 236 50.0 15.80 1.16 2,843.0 2,343.0 Page 2/2 Report Printed: 2/11/2011 • • piiii Cement Detail Report We CD3 -123 ConoeoPhillips y' ' String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/1/2010 06:00 CO Details - . . g' s Y" F. =' `, Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/5/2010 01:00 4/5/2010 03:45 CD3 -123 Comment 42 Obis Returned to Surface Cement.Stagei sf4 e T - i , Stare #'9` <:i. iit-- - 4 . i t , Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 2,834,0 Yes 42.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 8 500.0 1,100.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Bit 8 3/4 1 Comment c ement Fluids & Additives = Fluid -. _ = _ , -4. � ; . = - ° � .��: Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,343.0 400 G 321.0 Yield (ft' /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.52 21.23 10.70 7.00 Additives Additive Type Concentration Conc Unit label Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,843.0 2,343.0 236 G 50.0 Yield (ft'/sack) Mix H2O Ratio (gailsa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 4.50 Additives Additive Type Concentration Conc Unit label r' Page 1/1 Report Printed: 2/11/2011 • • A.-: Cement Detail Report ��� CD3 -123 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/1/2010 06:00 Cement Det iIs -' = - Description Cementing Start Date Cementing End Date Welibore Name Surface Casing Cement 4/13/2010 10:09 4/13/2010 10:29 . CD3 - 123 Comment Filled annulus of 16" (1.031" wall thickness) x 9.625" casing with water from tag of 32' below landing ring, taking retums in the cellar from landing ring.. Took 3 bbls to fill, using centrifugal pump. Mix and pump 6 bbls of ASI cement @ 15.7 ppg (.93 cuft/sx) (3.553 gal /sx water) (1:47 thickening time), using centrifugal - pump. Pumped all the cement allowing returns to cellar, sucking cellar w/ vac truck. Pulled out the 3/4" hose from between the conductor and surface pipe. Then sucked the cement down to 20" (1.67') below the top of landing ring. Cement Stages - Stage # -1- _ < ., .. , a - : y . 0 �`' - g Description Objective Top (ftKB) Bottom (ftKB) Full R Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement top fill conductor w/ 37.8 68.1 No No No cement from 32'. Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 1 1 92,0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment Filled annulus of 16" (1.031" wall thickness) x 9.625" casing with water from tag of 32' below landing ring, taking retums in the cellar from landing ring.. Took 3 bbls to fill, using centrifugal pump. Mix and pump 6 bbls of ASI cement @ 15.7 ppg (.93 cuft/sx) (3.553 gal /sx water) (1:47 thickening time), using centrifugal pump. Pumped all the cement allowing returns to cellar, sucking cellar w/ vac truck. Pulled out the 3/4" hose from between the conductor and surface pipe. Then sucked the cement down to 20" (1.67') below the top of landing ring. GementFtuids & Aiiditives -' - g - - :off Fluid _ . _ r,- , i . mss 's o c -s`, ic?' 4: Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water 3.0 Yield (ft (sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Conc Unit label \ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ` Class Volume Pumped (bbl) Arctic Set! 37.8 68.1 37 G 6.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (1b/gal) Plastic Viscosity (cp) Thickening Time (hrs) Cmprstr 1 (psi) 0.93 3.55 15.70 1.73 Additives Additive Type Concentration Conc Unit label D013 %BWOC Additive Type Concentration Conc Unit label D044 0.05 %BWOC Additive Type Concentration Conc Unit label D053 0.57 %BWOC Additive Type Concentration Conc Unit label D065 %BWOC Additive Type Concentration Conc Unit label D097 0.38 %BWOC Page 1/1 Report Printed: 2/11/2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -123 Rig: Doyon 19 Date: 4/6/2010 Volume Input Volume /Stroke Pump Rate: Drilling Supervisor: D. Burley / J. Browning Pump used: #2 Mud Pump V Strokes 0.1000 Bbls /strk 7.0 Strk/min Type of Test: OpenholeTest LOT /FIT ■ Pumping down annulus and DP. Casing Test Pressure Integrity Test Hole Size: 8 -3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 36.0IFt 2,833IFt -MDI 2,462f Ft -TVD 2,863IFt -MD 1 2,481IFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC v 0 0 0 3500 0 0 0 930 Casing Test Pressure IntegritvTesl 2 100 1 3500 1 40 0.25 900 Mud Weight: 9.6 ppg Mud Weight: 9.5 ppg 4' 225 2 3500 2 90 0.5 820 Mud 10 min Gel: 7.0 Lb /100 Ft2 Mud 10 min Gel: 35.0 Lb /100 Ft2 6 500 3 3475 3 180 1 745 Test Pressure: 3,500 psi Rotating Weight: 134,000 Lbs 8 750 4 3475 4 290 1.5 Rotating Weight: 129,000 Lbs Blocks /Top Drive Weight: 74,000 Lbs 10 900 5 3475 5 400 2 725 Blocks /Top Drive Weight: 74,000 Lbs Desired PIT EMW: 18.0 ppg 12 1100 6 3475 6 490 2.5 720 Estimates for Test: 2.5 bbls Estimates for Test: 1088 psi 0.8 bbls 14 1250 7 3475 7 580 3 715 -L . 16 1450 8 3475 8 670 3.5 710 EMW = Leak -off Pressure + Mud Weight = 790 + 9.5 PIT 15 Second 18 1700 9 3475 9 770 4 705 0.052 x TVD 0.052 x 2462 Shut -in Pressure, psi 20 1900 10 3475 10 830 4.5 700 EMW at 2833 Ft -MD (2462 Ft -TVD) = 15.7 ppg 900 22 2150 15 3475 I 1 880 5 695 4000 — Lost 50 psi during test, held — 24 2350 20 3475 12 940 5.5 690 — - 9 8.6% of test pressure. = 26 2650 25 3475 13 980 6 690 3500 — - • yt • • • A 28 2850 30 3450 14 1020 6.5 685 . — 30 3100 15 1010 7 680 3000 .— - = 32 3400 16 960 7.5 680 33 3500 8 675 w 2500 • 8.5 675 — 9 670 • 0 2000 • - - • — 9.5 670 ' --- 10 670 d 1500 • — 1000 - - 500 0 o 1 2 3 4 0 5 10 15 20 25 30 Volume Volume Volume Volume Barrels Shut -In time, Minutes ■■CASING TEST ■- -LEAK -OFF TEST O PIT Point Pumped Bled Back Pumped Bled Back 3.3 Bbls IBbls 1.6 Bbls IBbls Comments: 1 • CD3 -123 Intermediate Well: CD3 -123 7" 26 ppf L -80 BTC -m Casing Date: 4/11/2010 ConocoPhdlips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments , Length Tops Pagel y Top of String or Top of Flange RKB to Casing Flange (Load shoulder 34.23') (LLDS 33.61') 33.61 FMC 7" Mandrel hanger 1.00 33.61 7 ", 26 #, L -80, BTC -m Casing Pup jt Pin x Pin 2.22 34.61 Jts 122 to 262 141 Jts 7 ", 26 #, L -80, BTC -m Casing 5913.26 36.83 HES 7" Stage Collar 2.43 5950.09 Jts 4 to 121 118 Jts 7 ", 26 #, L -80, BTC -m Casing 4957.81 5952.52 HES Shut -off Baffle Collar 1.00 10910.33 Jts 3 to 3 1 Jts 7 ", 26 #, L -80, BTC -m Casing 42.36 10911.33 HES Sure Seal II Float Collar w/ By -Pass Baffle Adapter 1.01 10953.69 Jts 1 to 2 2 Jts 7 ", 26 #, L -80, BTC -m Casing 84.61 10954.70 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 11039.31 Bottom of shoe »> 11041.43 8 -3/4" Hole TD A 11053' MD / 6953.3 'TVD, Hole angle 84.43 deg 11041.43 7" Shoe A 11041.34' MD / 6952.2' TVD/ Hole angle 84.43 deg 11041.43 Rat hole 11.66'. 11041.43 Total of 91 Straight Blade centralizers (7" x 8 -3/8 ") - 5 Stop Collars 11041.43 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 11041.43 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 11041.43 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 11041.43 1 Straight Blade centralizer per jt on jts # 4 - #30 floating 11041.43 11041.43 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. #121 11041.43 1 Staight Blade centralizer w/ stop 10' above Stage Collar -Jt. #122 11041.43 1 Straight Blade centralizer per joint floating # 123 thru # 147 11041.43 11041.43 1 on 3 jts Across Shoe jts # 197, #198 & 199 11041.43 then 1 every other jt # 201 to # 261 11041.43 11041.43 11041.43 11041.43 11041.43 Planned: 280 jts in pipe shed / 262 jts to run. 11041.43 18 joints left in the shed 11041.43 11041.43 11041.43 Remarks: Drifted w/ 6.151" plastic rabbit Up Wt 280 K Average MU torque= 7800 Ft Ibs Dn Wt 170 K Used Run -N -Seal dope Block Wt 80 K While running pipe last: PU wt 320k, SO wt 175k numbers to the right are final while cementing Supervisors: Dave Burley / Granville Rizek PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD3 -123 I Rig:I Doyon 19 IDate: I 4/12/2010 I Volume Input Pump Rate: Drilling Supervisor: r I D. Burley / G. Rizek (Pump used: Cement Unit Barrels 0.1000 Bbls /strk ■ 0.8 Bbl /min Type of Test: Annulus Leak Off Test for Disposal Adequacy II Pumping down annulus. V ' - - -- Casing Test Pressure Integrity Test Hole Size: 8 -3/4" 17 Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: IFt 2,833 IFt-MDI 2,462IFt -TVD 4,890IFt -MD I 3,727IFt -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC V 0 0 0 587 Changes for Annular Adequacy Tes Pressure IntegrityTesl 1 0.5 67 0.25 527 L, '4 outer casing shoe test result in comments Mud Weight: u.2 ppg 2 1 119 0.5 523 r -) Description references oute casing string Inner casing OD 7.0 In. 3 1.5 196 1 515 Size is that drilled below oute casing. 4 2 261 1.5 stimated TOC for Hole Depth 5 2.5 320 2 510 Enter inner casing OD at right Desired PIT EMW: 14.5 ppg 6 3 375 2.5 507 Estimates for Test: 551 psi 0.3 bbls 7 3.5 411 3 505 ■ 8 4 448 3.5 504 EMW = Leak -off Pressure + Mud Weight = 640 + 10.2 PIT 15 Second 9 4.5 475 4 502 0.052 x TVD 0.052 x 2462 Shut -in Pressure, psi 10 5 511 4.5 502 EMW at 2833 Ft -MD (2462 Ft -TVD) = 15.2 527 15 5.5 553 5 500 1000 - - - - 20 6 579 5.5 498 25 6.5 612 6 496 ■■■■■ 30 7 640 6.5 495 7.5 635 7 493 ■■■■■ 8 624 7.5 493 111.11111.. 8.5 605 8 492 4111116 c, 9.5 590 8.5 9 490 soo ■■■■ 10 588 9.5 488 cn RINI. 10.1 588 10 488 cc 1111111..11.1 a ■■■■■ - 1, 7 11.1""- ■■■■■ o ■■■■■■ 0 2 4 6 8 10 12 0 5 10 15 20 25 30 Volume Volume Volume Volume Barrels Shut -In time, Minutes ∎trCASING TEST (LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls LBbls 11.0 Bbls LBbls Comments: 9 5/8" casing LOT = 15.7 ppg EM'A • • Security Level: AK Development Difling Daily Drilling Report CD3-123 Report Number: AO ConocoPtutlips Rig: DOYON 19 Report Date: 4/10/2010 . _ : - : = E " 7 " 10278811 9,750,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-123 Development FIORD NECHELIK 8.50 10.0 0.00 11,053.0 11,053.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 11,018.57 336,103.98 216,123.57 2,854,402.98 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/1/2010 4/2/2010 27.01 20.63 6.38 4/21/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,833.0ftKB Ops and Depth @ Morning Report 24hr Forecast Running 7" casing © approx 1400'. Finish changing top pipe rams to 7", test rams to 250 psi and 3500 psi, pull test plug, set casing running wear bushing , rig up to run, then run 7" 26 ppf L-80 BTC-m casing, circ, cement casing. Last 24hr Summary Continue to backream out of the hole pumping 650 gpm w/ 2550 to 2480 psi, rotate 100 rpm w/ 12.5 k ft lbs of torque, pulling speed 20'/min from 10414' to 9202', circulate bottom's up while backreaming f/ 9202' to 9107' pulling 2'-3'/minute, flow check-static, run in the hole from 9107' to 9202', blow down the top drive, con't to run in the hole from 9202' to 11008', make a top drive connection, then precautionary ream from 11008' to TD at 11053'. Backream out of the hole from 11053' to 10843' while circulating hole clean and weighting up from 9.8 ppg to 10.0 ppg. Pulling speed 4'/minute. Obtain slow pump rates. Trip in the hole to 11053'. Circulate 378 gpm w/ 1430 psi, loading casing running pill into the drill pipe. Pull out of the hole, laying in the casing running pill. Pumping 126 gpm, pulling 30'/minute from 11053' to 9202'. Blow down the top drive. Pull out of the hole on elevators f/ 9202' to 3495' (wipe tight spots @ 6272', 4731', 4700' and 3640'), monitoring the well on the trip tank. Backream f/ 3495' to 2640' (cleaning up the 8-3/4" open hole & 9-5/8" surface casing), pumping 600 gpm w/ 1600 psi, rotate 115 rpm w/ initial 8k ft lbs, final 5.5k ft lbs of torque. ECD spikes of 11.41 at 2929' and 11.07 ppg © 2830'. Monitor well, pull out of the hole on the trip tank from 2640' to 740'. Monitor well © the HWDP- static, continue to pull out of the hole to 78', plug in to download MWD, break bit, clean floor, lay down BHA #2. Wash stack w/ 800 gpm and 530 psi w/ stack washing tool (45' to surface), lay down tool. Blow down the top drive, set back a stand of 5" drill pipe. Pull FMC long (10" ID) wear bushing. Pre Job safety meeting. Changing upper pipe rams from 3-1/2" x 6" to 7" solid body. General Remarks Weather Head Count No Accidents - No Spills- Running one engine w/ Hi-line. 19°,WC 15° Wind S @ 14 Mph, 10 mile vis 51.0 Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer Tithe Lao r - Start - End : Dur T oott;§tart Time Time : (his) ?MfdCar:: peratlon 00:00 02:15 2.25 INTRM1 DRILL REAM P 10,414.0 9,202.0 Continue to backream out of the hole pumping 650 gpm w/ 2550 to 2480 psi, rotate 100 rpm w/ 12.5 k ft lbs of torque, pulling speed 20'/min from 10414' to 9202'. 02:15 02:45 0.50 INTRMI DRILL CIRC p 9,202.0 9,107.0 Circulate bottom's up while backreaming f/ 9202' to 9107' pulling 2'-3'/minute, pumping 650 gpm w/ 2480 psi, rotate 100 rpm w/ 12.0 k ft lbs of torque. 02:45 03:00 0.25 INTRMI DRILL OWFF p 9,107.0 9,202,0 Run in the hole from 9107' to 9202'. Flow check-static. Blow down the top drive. 03:00 04:00 1.00 INTRMI DRILL TRIP P 9,202.0 11,008.0 Continue to run in the hole from 9202' to 11008'. 50' to 60'/minute. Obtain PU and SO wt's every 5 stands. Hole took 5k at 10442' and 10880', then 15k at 10986'. Worked these areas- OK. PU wt 247k, SO wt 173k. 04:00 04:15 0.25 INTRM1 - DRILL REAM p 11,008.0 11,053.0 Make a top drive connection, then precautionary ream from 11008' to TD at 11053'. Pumping 650 gpm w/ 2580 psi, rotate 100 rpm w/ 12.0 k ft lbs of torque Latest BOP Test Data 4/5/2010 Witnessed by Bob Noble, AOGCC Page 1/3 Report Printed: 2/11/2011 • • Security Level: AK Development Daily Drilling Report KA • ma &MMUS . , CD3-123 Report Number: 10 ConocoPhillips • Rig: DOYON 19 Report Date: 4/10/2010 nice Start: End Dur - • _ Depth Start ;Deptt7intv_40. Time (his) Phase Op Code Trbl:COdia:= TrbI Class (ftO) 04:15 05:30 1.25 INTRMI DRILL REAM P 11,053.0 10,843.0 Backream out of the hole from 11053 to 10843' while circulating hole clean ( two bottom's up) and weighting up from 9.8 ppg to 10.0 ppg. Pumping 650 gpm w/ 2580 psi, rotate 100 rpm w/ 12.0 k ft lbs of torque, pulling speed 4'/min. 05:30 05:45 0.25 INTRMI DRILL CIRC P 10,843.0 10,843.0 Obtain slow pump rates. 05:45 06:00 0.25 INTRMI DRILL TRIP P 10,843.0 11,053.0 Trip in the hole from 10843' to 11008'. Make a top drive connection. Ream to bottom @ 11053'. PU wt 246k, SO wt 176k. 06:00 06:30 0.50 INTRMI DRILL CIRC P 11,053.0 11,053.0 Circulate, loading casing running pill in the drill pipe. Pumping 378 gpm w/ 1430 psi. Rotate 100 rpm w/ 12.5k ft Ibs of torque. Note: Casing running pill consists of 70 bbls new Glydril mud, 110 bbls mud f/ active pits, then 5 ppb each: Safe Carb 40, Safe Carb 250, Sack black, Alpine beads. 06:30 08:30 2.00 INTRMI DRILL TRIP P 11,053.0 9,202.0 Pull out of the hole while pumping, laying in the casing running pill from 11053' to 9202'. Pumping 126 gpm w/ 230 psi., pulling 30/minute. 08:30 08:45 0.25 INTRM1 DRILL OTHR p 9,202.0 9,202.0 Blow down the top drive. Line up the trip tank. 08:45 12:00 3.25 INTRM1 • DRILL TRIP 9,202.0 6,065.0 Pull out of the hole on elevators from 9202' to 6065. Monitor well on the trip tank. At 6065': PU wt 185k, SO wt 152'. Tight spot at 6272'. 12:00 13:15 1.25 INTRMI DRILL TRIP P 6,065.0 3,495.0 Crew change, then continue to pull out of the hole on elevators from 6065' to 3495'. Monitor well on the trip tank. Tight spots @ 4731', 4700' and 3640'. Wiped tight spots. 13:15 13:30 0.25 INTRM1 DRILL OTHR p 3,495.0 3,495.0 Line up to circulate. Make a top drive connection. 13:30 15:45 2.25 INTRMI DRILL REAM p 3,495.0 2,640.0 Backream from 3495' to 2640, cleaning up the 8-3/4" open hole & 9-5/8" surface casing.. Pumping 600 gpm w/ 1600 psi. Rotate 115 rpm w/ initial 8k, final 5.5k ft • Ibs of torque. ECD spike of 11.41 ppg @ 2920', ECD spike of 11.07 ppg @ 2830% 15:45 16:00 0.25 INTRMI DRILL OWFF P 2,640.0 2,635.0 Monitor well- static. 16:00 18:30 2.50 INTRMI DRILL TRIP 2,635.0 740.0 Pull out of the hole f/ 2635' to 740', monitor on the trip tank. Remove ghost reamer @ 1824'. 18:30 18:45 0.25 INTRM1 DRILL OWFF P 740.0 618.0 Monitor well at the HWDP (740')- static. Pull out to ghost reamer @ 618', lay down ghost reamer. 18:45 19:45 1.00 . INTRM1 DRILL TRIP p 618.0 78.0 Continue to pull out and stand back HWDP, jars, stand of 6-3/4" flex drill collars, and integral blade stabilizer from 618' to 78'. Page 2/3 Report Printed: 2/11/2011 • • Security Level: AK Development a ..]►,hilt Daily Drilling Report it . +:_ &Wei CD3 -123 Report Number: 10 ConocoPhillips v. Rig: DOYON 19 Report Date: 4/10/2010 Time Log _-:: _ -' -_= o-_ Start End Dar °- _ • ,Txne' Depti Start - Dep(hEnd V t Time. Time - (hrs) . . Phase Op Code °ActMty Code :-::,=-: . PTXX : Trbl Code - Trbi Class - (1 :1 (ftK6) _ ' . 7 . n Operation J 4 19:45 21:00 1.25 INTRMI DRILL OTHR P 78.0 78.0 Make up lift sub, then pick up, plug in to download, continue to pick up and break bit while downloading MWD. Clean floor. 21:00 21:45 0.75 INTRMI DRILL PULD P 78.0 0.0 Lay down BHA #2 from 78'. 21:45 22:15 0.50 INTRMI DRILL CIRC P 0.0 0.0 Make up stack washing tool, run in to 45', wash stack 800 gpm w/ 520 psi. Work twice. 22:15 22:30 0.25 INTRM1 DRILL TRIP P 0.0 0.0 Blow down the top drive. Set back a stand of 5" drill pipe. 22:30 23:00 0.50 INTRMI WHDBOP OTHR P 0.0 0.0 Pull FMC long wear bushing (10" ID). Note: Noticed a small piece of iron, below top seal, when wear bushing was pulled out. 23:00 23:15 0.25 INTRM1 WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on changing top pipe rams. 23:15 00:00 0.75 INTRMI WHDBOP NUND P 0.0 0.0 Change upper pipe rams from 3 -1/2" x 6" to 7" solid body rams. Sim ops, working to rig up top drive for running 7" casing. Mud Check DataT _I _ - YP Calc Gel (10s) Get(10m) _ - . Gel (30m) IiTHP Filt : Density Temp = Solids Corr: Type - . Depth (ftKB) - Dens pb/gaI) (slat) E PV Calc (cp). - :(Ibf(100ft 2 ) ' , /100th), . - (lbfMoof") =. (Ibf/100t) MBT"(lii)bblf _(rt1U3O01) - pH . ` (°F) _ '.(%). LS N D w/ 11,053.0 10.00 37 9.0 15.0 5.0 8.0 10.000 19.0 8.9 9.0 10.0 Glydril LSND w/ 11,053.0 10.00 39 9.0 15.0 6.0 8.0 9.000 19.0 8.7 9.0 10.0 Glydrii LSND w/ 0.0 9.80 41 9.0 17.0 6.0 9.0 10.000 18.5 9.0 9.0 Glydrii Injection Fluid :- Fluid - ,.Source , From Lease (bbl) ` Destinations . :Vendor Manfest Number Note: . - Diesel 5.0 CD3 -304 Injectivity Diesel 5.0 CD3 -304 Freeze protect Water Based Mud CD3 -123 290.0 CD3 -304 Well bores L Welibore Name Wellbore API/UWI CD3 - 123 501032061700 _ : = Section ` = ,'. - > <.__:Size (In) .:.. ".. :` . , -Act Top (fIKB) -' ._ n1(ftK -Act B) v : ,: 4: ...Statt :Date ;: -- ` _:: <: :,- 'En p d:Date - : °.: ,.- CONDI 19 36.0 114.0 SURFAC 12 1/4 36.0 2,843.0 4/2/2010 4/4/2010 INTRM1 83/4 2,843.0 11,053.0 4/6/2010 4/9/2010 PROD1 6 1/8 11,053.0 17,142.0 4/15/2010 4/20/2010 • At Page 3/3 Report Printed: 2/11/2011 • • Security Level: AK Development .;� Daily Drilling Report 1liE CD3 -123 Report Number: 11 ConocoPhiilips Rig: DOYON 19 Report Date: 4/11/2010 e << - �_. _ , , � .: AFE TYpe._ => - - .,. • ., , -. -- ::NetworlcllD # ' °; .. , - 10278811 9,750,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -123 Development FIORD NECHELIK 9.50 11.0 0.00 11,053.0 11,053.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 11,423.60 347,527.58 233,051.60 3,087,454.58 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Protected Job End Date 4/1/2010 4/2/2010 27.01 21.63 5.38 4/22/2010 Last Casing String Next Casing OD (In) Next Casing Set Depth (ftKB) SURFACE, 2,833.OftKB Ops and Depth @ Morning Report 24hr Forecast Displace cement on 1st stage 7" cement job. Circulate, cement 7" casing - 1st and second stage, rig down cement & casing equipment, install & test packoff, lay down 5" dp, change rams to 3 -1/2'x 6", test BOPE. Last 24hr Summary Continue changing upper pipe rams from 3 -1/2" x 6" to 7" solid body, rig up to test, test rams to 250 psi and 3500 psi f/ 5 minutes each: Chart test. Rig down testing equipment. Set FMC casing running wear bushing (10- 15/16" OD x 10 -3/8" ID x 1.53' long), lay down running tool. PJSM, then rig up to run 7" 26 ppf L -80 BTC -m casing. PJSM, then run 7" casing per detail- circulate @ 2815', 5039', 7315', and 9403'. Once landed on hanger w/ shoe @ 11041', rig down Frank's fillup tool, make up Dowell cement head, continue to circulate stagging pumps from 3.5 bpm w/ 380 psi to final of 6 bpm w/ 450 psi. Held pre job safety meeting on cement job while circulating. Note: Held Safety Standown with crew coming out at noon. Time of meeting 0945 hrs. Held Safety Standown with crew coming out at midnight. Time of meeting 2145 hrs. Held Safety Standown with crews @ MI mud plant. Time of meeting approx 1730 hrs. General Remarks Weather Head Count No Accidents - No Spills- Running one engine w/ Hi -Line. 18 °,WC 9° Wind S @ 7 Mph, 10 mile vis 51.0 _ - = Supervisor TAIe - Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer Time Log_ ::Start End Dta _ ' a - - a.:. Tlme Depth St @rt Depth End �� a Time . Time (hrs) ' Phase Top Code ActMty Code P T X -- Trbl Code _ Trb Class -- . i4(ftKB),_ - (ftKB} _ Operatwn 00:00 00:15 0.25 INTRMI WHDBOP NUND P 0.0 0.0 Continue changing upper pipe rams from 3 -1/2" x 6" to 7" solid body. 00:15 00:45 0.50 INTRMI WHDBOP BOPE P 0.0 0.0 Set FMC test plug. Rig up to test 7" upper pipe rams. Fill stack with water. Lower annulus open. 00:45 01:00 0.25 INTRMI WHDBOP BOPE P 0.0 0.0 Test upper pipe rams to 250 psi and 3500 psi f/ 5 minutes each. Chart test. 01:00 01:15 0.25 INTRMI WHDBOP RURD P 0.0 0.0 Rig down testing equipment. 01:15 01:30 0.25 INTRMI WHDBOP RURD P 0.0 0.0 Set FMC thin wall casing running wear bushing (10- 15/16" OD x 10 -3/8" ID x 1.53' long), lay down running tool. 01:30 01:45 0.25 INTRM1 CASING SFTY P Pre job safety meeting on rigging up to run 7" 26 ppf L -80 BTC -m casing. 01:45 02:30 0.75 INTRM1 CASING RURD P 0.0 0.0 Finish rigging up to run 7" 26 ppf L -80 BTC -m casing. 02:30 02:45 0.25 INTRMI CASING . SFTY P 0.0 0.0 Pre job safety meeting on running 7" 26 ppf L -80 BTC -m casing. Latest BOP Test Data Data _ ::_> Y , Comment 4/5/2010 ' Witnessed by Bob Noble, AOGCC Page 1/3 Report Printed: 2/11/2011 • • Security Level: AK Development Daily Drilling Report tkWellis CD3-123 Report Number: 11 ConocoPhillips Rig: DOYON 19 Report Date: 4/11/2010 Time Log Start: s:. ; :Time : - DepthSteit DpftiEnd Time Time ..._(tie) 0.-TX- trtil dass. oticarl: 02:45 03:15 0.50 INTRM1 CASING RNCS P 0.0 165.0 Run 7" casing per program:Pick upjt#1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8-3/8") floating from shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7"x8-3/8" aluminum centralizer between box and 10' below box with stop ring.Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock joint #3 w/ ray Oil Tool aluminum centralizer (7" x 8-3/8") floating f/ pin to 10' above pin with stop ring.Baker lock Halliburton Baffle adapter, then baker lock pin of joint #4 with centralizer floating the full joint. Four connections were baker locked. 03:15 03:30 0.25 INTRMI CASING CIRC P 165.0 165.0 Stab Frank's fill up tool into box of joint #4. Then circulate 25 bbls of mud to check floats. Pumping up to 6 bpm w/ 300 psi. 03:30 06:00 2.50 INTRM1 CASING RNCS 165.0 1,680.0 Continue to run 7" 26 ppf L-80 BTC-m casing g/ 165' to 1680' (40 joints in the hole). PU wt 110k, So wt 109k. Obtain PU and SO wt's per rig engineer. 06:00 07:15 1.25 INTRMI CASING RNCS 1,680.0 2,815.0 Continue to run 7" 26 ppf L-80 BTC-m casing g/ 1680' to 2815' (67 joints in the hole). PU wt 110k, SO wt 109k. Obtain PU and SO wt's per rig engineer. 07:15 07:45 0.50 INTRMI CASING CIRC P 2,815.0 2,815.0 Circulate, staged pumps up from 3.5 bpm w/ 250 psi - FCP 7 bpm w/ 440 psi. Circulated 120 bbls - highest MW out 10.0 ppg PUW 130K SOW 122K 07:45 10:15 2.50 INTRMI CASING RNCS P 2,815.0 5,039.0 Continue to run 7" 26 ppf L-80 BTC-m casing f/ 2815 to 5039' (174 joints in the hole). PU wt 177k, SO wt 143k. Obtain PU and SO wt's per rig engineer. 10:15 11:00 0.75 INTRMI CASING CIRC P 5,039.0 5,039.0 Circulate, staged pumps up from 3.5 bpm w/ 320 psi - FCP 7 bpm w/ 570 psi. Circulated 256 bbls - highest MW out 10.2 ppg PUW 170K SOW 143K 11:00 13:30 2.50 INTRM1 CASING RNCS P 5,039.0 7,315.0 Continue to run 7" 26 ppf L-80 BTC-m casing f/ 5039 to 7315' (174 joints in the hole). PU wt 245k, SO wt 157k. Obtain PU and SO wt's per rig engineer. 13:30 14:45 1.25 INTRMI CASING CIRC P 7,315.0 7,315.0 Circulate, staged pumps up from 3.5 bpm w/ 375 psi - FCP 6 bpm w/ 530 psi. Circulated 340 bbls - highest MW out 10.35 ppg PUW 225K SOW 160K 14:45 17:00 2.25 INTRMI CASING RNCS P 7,315.0 9,403.0 Continue to run 7" 26 ppf L-80 BTC-m casing f/ 7315 to 9403' (224 joints in the hole). PU wt 285k, SO wt 175k. Obtain PU and SO wt's per rig engineer. A Page 2/3 Report Printed: 2/11/2011 • _ Security Level: AK Development - - : T � ii i in. Daily Drilling Report 4. &Wells CD3-123 Report Number: 11 LonocoPhillips Rig: DOYON 19 Report Date: 4/11/2010 Time:Loa = Start End Dur , - - k Time Depth Stan Depth End = Phase 013 Code ActlAtl - Trbl Class. --(ftKEi) ::(flKS) 17:00 18:30 1.50 INTRMI CASING CIRC P 9,403.0 9,403.0 Circulate, staged pumps up from 3.5 bpm w/ 440 psi - FCP 6 bpm w/ 560 psi. Circulated 470 bbls - highest MW out 10.35 ppg PUW 275K SOW 173K 18:30 20:45 2.25 INTRMI CASING RNCS 9,403.0 11,000.0 Continue to run 7" 26 ppf L-80 BTC-m casing f/ 9403 to 11000' (262 joints in the hole). PU wt 285k, SO wt 175k. Obtain 4' PU and SO wt's per rig engineer. 20:45 21:00 0.25 INTRM1 CASING RNCS P 11,000.0 11,041.0 Make up FMC 7" hanger and landing joint. Run in hole and land on hanger with shoe at 11041'. PU wt 320k, SO wt 175k. 21:00 21:15 0.25 INTRM1 CEMENT RURD P 11,041.0 11,041.0 Blow down the top drive. Make up Dowell cement head. attatch hose and valves to head. 21:15 00:00 2.75 INTRM1 CEMENT CIRC P 11,041.0 11,041.0 Circulate and condition mud and hole for cement job. Stage pumps up from 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Note: Held Safety standown with crew coming out at noon. Time of meeting 0945 hrs. Held Safety standown with crew coming out at midnight. Time of meeting 2145 hrs. Held Safety standown with crews MI mud plant. Time of meeting approx 1730 hrs. Mud Check Data - = ' YP Cale - Gel (1Os) Gel (710m), Density:Tim ::Sodsi'-Co rt.:: Type : - Depth (ffKB) Dens (RAO Vls (skit) :PV Cato (ep) 09109n obr000rtl... (tartmoft:Tp 14617-61i/beli' LSND w/ 11,053.0 10.00 43 11.0 15.0 6.0 8.0 11.000 19.0 8.7 9.0 Glydril LSND w/ 11,053.0 10.00 43 10.0 17.0 6.0 9.0 0.000 19.0 0.0 10.0 Glydril Fluid , Source - - From Lease -----„bestination' Manifest Number Diesel 30.0 CD3-304 Freeze Protect Water 150.0 CD3-304 Water Based Mud CD3-123 232.0 CD3-304 ASRC 340217 Water Based Mud CD3-123 164.0 CD3-304 WeUbores - = Wellbore Name Wellbore API/UWI CO3-123 501032061700 Section . Sze(in) - Act Top (ftKEI),_,... , Ent» (ftKB) - Start Date - , COND1 19 36.0 114.0 SURFAC 12 1/4 36.0 2,843.0 4/2/2010 4/4/2010 INTRMI 83/4 2,843.0 11,053.0 4/6/2010 4/9/2010 PROD1 61/8 11,053.0 17,142.0 4/15/2010 4/20/2010 Page 3/3 Report Printed: 2/11/2011 • • ,l n Cement Detail Report .4 &Wells CD3 -123 ConocoPhillips ' • String: Cement Intermediate Job: DRILLING ORIGINAL, 4/1/2010 06:00 Cement Details' ,. _ _v_ - Z . _1 . Description Cementing Start Date Cementing End Date Welibore Name Cement Intermediate 4/12/2010 04:38 - 4/12/2010 09:15 CD3 - 123 Comment Circ & cond mud & hole for cmt job. Stage pumps up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Con't pumping 6 bpm w/ 450 to 480 psi. Recip 7" csg 30' stroke f/ 11041' to 11011'. PU wt 295k, SO wt 175k. Flow check well, slight flow. Air In the mud. Increase MW from 10.0 ppg to 10.2 ppg precautionary. Pumping 6 bpm w/ 470 to 530 psi. Dowell pump 2 bbl CW 100, PT lines to 3500 psi. Pump another 38 bbls of CW100 (40 bbis total) @ 4 bpm w/ 350 to 380 psi. Mix & pump 35 bbls 11.5 ppg mud push @ 4 bpm w/ 330 final pressure, shut down. Load Halliburton bottom plug, kick out plug w/ 5 bbls more MudPush f/ a total of 40 bbis. Load Halliburton top plug. Dowell pump 64.2 bbls 15.8 ppg (310 sx) (1.16 cuft/sx) (5.08 gal /sx water) (5.34 hr thickening time). Drop Halliburton top shut off plug. Kick plug out with 20 bbis water, pumping 6 bpm w/ 118 to 72 psi. Rig displ cmt w/ 10.2 ppg mud, pumping 6 bpm w/ initial 120 psi, final 630 psi. Stayed on hanger (10 bbls before and 10 bbls after) when CW100, MudPush II and cmt came around shoe, then con't recip. Recip'd 30' stroke until slowing displacement to 3 bpm w/ 420 psi initial & 430 psi final for last 5.4 bbls prior to bumping plug w/ 930 psi @ 0652 hrs 4/12/2010. Held press • f/ 5 minutes, then bleed off & checked floats -OK. Load Halliburton 2nd stage closing plug in the cement head. Note: Final PU wt 280k, Final SO wt 170k. Open Halliburton stage tool @ 5950' with 3330 psi applied. Circ & cond mud f/ cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. Dowell pump 30 bbl CW 100 @ 4 bpm w/ 208 to 257 psi. Mix and pump 30 bbls 11.5 ppg mud push @ 5.2 bpm w/ 275 psi final , shut down. Dowell mix, then pump 41 bbls 15.8 ppg (198 sx) (1.16 cuft/sx) (5.11 gal /sx water) (5.34 hr thickening time). Drop Halliburton closing plug. Kick plug out w/ 20 bbls water through the tub, rig displ 5 bpm w/ final 300 psi, slow to 3 bpm last 7.3 bbl, bump plug & tool shut w/ 1460 psi, press to 1930 psi, hold 5 minutes. - .Cement_Stages >: < -_ Stage #'t C• 1. ' 4r::. ::- . ; _-4 m Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Cement Intermediate 9,360.4 11,053.0 Yes Yes Yes Q (start) (bbl /min) Q (end) (bbl/min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 5 430.0 930.0 Yes 30.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Circ & cond mud & hole for cmt job. Stage pumps up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Con't pumping 6 bpm w/ 450 to 480 psi. Recip 7" csg 30' stroke f/ 11041' to 11011'. PU wt 295k, SO wt 175k. Flow check well, slight flow. Air in the mud. Increase MW from 10.0 ppg to 10.2 ppg precautionary. Pumping 6 bpm w/ 470 to 530 psi. Dowell pump 2 bbl CW 100, PT lines to 3500 psi. Pump another 38 bbls of CW100 (40 bbls total) @ 4 bpm w/ 350 to 380 psi. Mix & pump 35 bbis 11.5 ppg mud push @ 4 bpm w/ 330 final pressure, shut down. Load Halliburton bottom plug, kick out plug w/ 5 bbis more MudPush f/ a total of 40 bbls. Load Halliburton top plug. Dowell pump 64.2 bbls 15.8 ppg (310 sx) (1.16 cuft/sx) (5.08 gal /sx water) (5.34 hr thickening time). Drop Halliburton top shut off plug. Kick plug out with 20 bbls water, pumping 6 bpm w/ 118 to 72 psi. Rig displ cmt w/ 10.2 ppg mud, pumping 6 bpm w/ initial 120 psi, final 630 psi. Stayed on hanger (10 bbls before and 10 bbls after) when CW100, MudPush II and cmt came around shoe, then con't recip. Recip'd 30' stroke until slowing displacement to 3 bpm w/ 420 psi initial & 430 psi final for last 5.4 bbls prior to bumping plug w/ 930 psi @ 0652 hrs 4/12/2010. Held press f/ 5 minutes, then bleed off & checked floats -OK. Load Halliburton 2nd stage closing plug in the cement head. Note: Final PU wt 280k, Final SO wt 170k. Open Halliburton stage tool @ 5950' with 3330 psi applied. Circ & cond mud f/ cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. Cerftent Fluidal!, AdditiVea' agta" * - _ . .t f % 4, z tit 0: si ' 0 Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW 100 7,226.0 8,293.2 40.0 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.35 _ Additives Additive Type Concentration Conc Unit label Fluid - = _ - ' :: ==.r s ', '' = ":': , . ., = _ : * �.: :: l .. K,,4 ' .w ___ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) I MudPush II 8,293.2 9,360.4 40.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label FIitid __ - - _ W K: �_ -. N _ - r Fluid Type _ n fi0 4 Fluid Description Estimated Top (ftKB) Est Btm (ftKI) Amount (sacks) Class Volume Pumped (bbl) Alpine Tail cement 9,360.4 11,053,0 310 G 64.2 Yield (ft' /sack) . Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Page 1/2 Report Printed: 2/11/2011 0 0 Cement Detail Report Sr.- ' in , il ,.. „ .. & 8 ._, CD3-123 .::.:.. „ ConocoPhillips v String: Cement Intermediate Job: DRILLING ORIGINAL, 4/1/2010 06:00 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D046 AntiFoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Cement Stadlii::: -- .1.:::: I = ::, . ,.! f , :-, ,, ;--E*-i:5, , , , : : =.; , =;: ,::: , ':. - ---::: - ; , '=:=Y.,;:',::: - ;:::;.: :::::::: :: - ' :;: = :: ":: ':'la" ' ::::::-'• ' stEj60#4 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Cement Intermediate Cement Quannik 4,856.1 5,950.0 Yes Yes No formation Q (start) (bbl/min) IQ (end) (bbl/min) Q (avg) (bbl/min) IP (final) (psi) P (bump) (psi) Recip? IStroke (ft) Rotated? Pipe RPM (rpm) 4 3 5 250.0 1,930.0 No I No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment Rig pressure up to open Halliburton stage tool @ 5950'. Tool opened with 3330 psi applied. Circulate and condition mud for cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. Dowell pump 30 bbl CW 100 @ 4 bpm w/ 208 to 257 psi. Mix and pump 30 bbls 11.5 ppg mud push © 5.2 . ? bpm w/ 275 psi final pressure, shut down. Dowell mix, then pump 41 bbls 15.8 ppg (198 sx) (1.16 cuft/sx) (5.11 gal/sx water) (5.34 hr thickening time). Drop Halliburton closing plug. Kick plug out with 20 bbls water through the tub, pumping 6 bpm w/ 99 psi. Rig displace cement w/ 10.2 ppg mud, pumping 5 bpm w/ initial 70 psi, final 300 psi, slowing displacement to 3 bpm w/ 230 psi initial and 250 psi final for last 7.3 bbls prior to bumping plug w/ 1460 psi to close @ 01914 hrs, then pressure to 1930 psi @ 0915 hrs 4/12/2010. Held pressure f/ 5 minutes, then bleed off and checked floats-OK. Blow down lines. Note: Bumped plug 2.7 bbls early. COment ::.-',1' '21 -;' ,.':', A: 1:' : 3 ::4::[.i: -: . , --Aiti**:2;.'-::,.f==:: , ..iw,:i -.:;= , c--, - ,-:1-=-Z.:=ko:i - r' ::::-;R:V4Y5- .;:;: ',,,--- Fluid :rr:: rj;::: ' = ' '':-==, :f:.' Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 3,255.2 4,055.6 30.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.35 Additives Additive 'Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 4,055.6 4,856.1 30.0 Yield (ftlsack) Mix H20 Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cp) 'Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration IConc Unit label mild Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,856.1 5,950.0 198 G 41.0 Yield (fts/sack) Mix H20 Ratio (gal/sa... 'Free Water (%) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.11 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label 0046 AntiFoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 2/11/2011 • CD3 -125 Information Pack (Temporarily Suspended After Surface Hole — 02.06.11) • Casing OR Tubing OR Drilling Detail Well: CD3 -125 Description of Equipment Run with respect to Wellbore Date: 2/3/2011 ConocoPhillips Rig: Doyon 141 Alaska, Inc. Depth Jt Number Joints Well Equipment Description Ohs Length Tops Page 1 ............ .................. ......................... .................. ....................... ............ ................. Top of String or Top of Flange RKB to Top of Landing Ring 27.85 FMC 9 5/8" Casing Hanger 2.20 27.85 Jts 3 to 71 69 Jts 9 5/8 ", 40.0 #, L -80, BTC Casing 2839.52 30.05 HES 9 5/8" Sure Seal II Float Collar 1.20 2869.57 Jts 1 to 2 2 Jts 9 5/8 ", 40.0 #, L -80, BTC Casing 80.32 2870.77 Ray Oil Tools 9 5/8" Silver Bullet Float Shoe 2.24 2951.09 2953.33 2953.33 2953.33 Baker Lock 1st 3 joints and pin on 4th joint 2953.33 2953.33 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 2953.33 1 Bowspring Centralizer on stop collar 10' below the box of joint # 2 2953.33 1 Bowspring centralizer on stop 10' above pin on joint # 3 2953.33 Bowspring centralizers on joints # 4 -13. Then run Bowspring 2953.33 centralizer every other joint to surface 2953.33 2953.33 Centralizer placement highlighted in yellow on tally sheet. 2953.33 2953.33 2953.33 9 Joints of 9 -5/8" casing remain in shed 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 2953.33 Remarks: Up Wt ? ? ?K Dn Wt ?? K Block Wt ?? K Supervisors: Guy Whitlock, Mark Brouillet . • - - - - - Security Level: AK Development Milling Daily Drilling Report "Moos =, •• • • __ ,_. ...:_. CD3-125 .._. ..,_ . , -__ ••- Report Number: 7 ConocoPhillips Rig: DOYON 141 Report Date: 2/5/2011 ,„,,,,,-..,,:.„-, .:.:Nelwork/ID # , -'-' '- 10296869 8,975,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-125 Development FIORD NECHELIK 3.56 7.0 0.00 2,966.0 2,966.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 11,815.50 46,972.08 189,050.55 617,865.88 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/30/2011 2/2/2011 30.31 30.10 0.21 3/1/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,953.3ftKB Ops and Depth @ Morning Report 24hr Forecast Running 3-1/2" Tubing Kill String @ 330' N/U Casing head, BOP's, Shell Test, Run Kill String, Displace Last 24hr Summary Rig up & run 9-5/8" Surface casing. Circulate and condition, Cement per Program. Nipple down Surface stack, I ' General Remarks Weather Head Count No accidents or incidents. Rig and Camp on High Line -8° Wind 17 MPH West, Wind Chill -31° 44.0 S upervisor ,:.:: =,---: - , - '-- - --,.----,-;•;,,,,,,,--:::::::::, - ..,_ - : - ' ---:-- - E - : - : - _:•.. — ,:_:::::::-- : :----,..,,,,,,,', r:_:' Guy Whitlock, Rig Supervisor Rig Supervisor Mark Brouillet, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer 71161 ---,:':' - n :i'''' :' --End - : - Dur --- -::-:,-,: -PqPth Siert - ,V Frirife::: Time : (I* - !'-'-' -4 i,A51;:eci'Clig - :'-=..-:.:1-.-;ACtiiiiiCoclii :' , :"I`rtiratisi,"----:.:;(ftKE9 - 4-:::40.P,VWA,;-4W:**,- - OPitriticiii:=4:VM't.:Vi:O.0 00:00 01:00 1.00 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9-5/8" Surface casing 01:00 01:30 0.50 SURFAC CASING SFTY P 0.0 0.0 Pre Job Safety Meeting for running 9-5/8" Casing. Review running order, Discuss hazards associated with task. Hand pinch points, Positions of people, Watch out for casing stabber. 01:30 02:00 0.50 SURFAC CASING RNCS P 0.0 160.0 Pick up casing float equipment, Fill pipe check floats. (Joints baker locked.) 02:00 04:00 2.00 SURFAC CASING RNCS P 160.0 1,493.0 Run casing F/160' - T/ 1,485'. Good returns with no tight spots. 04:00 05:00 1.00 SURFAC CASING CIRC P 1,493.0 1,493.0 Circulate Bottoms up, Stage pumps up to 5 bbl per min with no losses. Reciprocate full joint. Mud wt in and out 10.0 ppg Vis out 300+ Vis in 259. Pumped 140 bbls while circulating. Annular capacity at 1,485' MD 83 bbl's. 05:00 07:00 2.00 SURFAC - CASING RNCS P 1,493.0 2,953.0 Run Casing to 2,925', Make up lamding joint, Land casing at 2,953' MD. Up wt 142k dn wt 85k. Calculated displacement 42.45 bbl's Actual displacement 36.5 bbl's 07:00 09:00 2.00 SURFAC CEMENT CIRC P 2,953.0 2,953.0 Circulate and condition through Franks fill up tool. Stage pumps up to 5 bpm with 400 psi. 404 bbl's circulated. Up wt [ 125k dn wt 100k. Sim ops rig down csg equip. 09:00 09:30 0.50 SURFAC CEMENT RURD P 2,953.0 2,953.0 PJSM, Rig down franks tool, Make up X-0 and cement head to landing joint. (Spill drill held during operation with 2 . min response time) 09:30 12:30 3.00 SURFAC CEMENT CIRC P 2,953.0 2,953.0 Circulate and condition for correct mud properties prior to cement job. 6 bpm flow rate with 400 psi. 125k up wt 100k down wt Latest BOP Test Data Page 1/3 Report Printed: 2/11/2011 1 • 0 Security Level: AK Development .■• Daily Drilling Report CD3-125 Report Number: 7 ConocoPhillips Rig: DOYON 141 Report Date: 2/5/2011 TLmeLoL Start Ehdt Time =: Depth Start Mlepth:Enckts 12:30 16:00 3.50 SURFAC CEMENT CMNT P 2,953.0 2,953.0 PJSM with cementer, Pump 80 bbl ' spacer viscosified nut plug, 50 bbl Desco pill, Swap over to Schlumberger, Pump 5 bbl's water, Pressure test lines to 3,500 psi. Bleed off pressure. Drop bottom plug. Pump 50 bbl mudpush © 10.5 ppg, Pump 337 bbl's 10.5 ppg Lead cement, Pump 49 bbl's 15.8 ppg Tail cement. Drop top plug. Chase with 20 bbl's water with DS. Displace cement with rig pumps 197.5 bbl's mud. Bump plug © 1,968 strokes. CIP at 15:23 hrs. Pressure up 500 psi over final circulating pressure. Bleed off pressure check floats. ( Floats Good) 16:00 16:30 0.50 SURFAC CEMENT PRTS P 0.0 0.0 Test casing to 3,500 psi for 30 min. Test Charted.) 16:30 19:30 3.00 SURFAC CEMENT RURD P 0.0 0.0 Rig down cement lines, Cement & Casing equipment, Lay down landing joint, Function diverter hydril and flush. Flush and wash surface stack. 19:30 22:00 2.50 SURFAC WHDBOP NUND P 0.0 0.0 PJSM, Nipple down surface stack, Clean and prep for casing head per FMC rep. 22:00 00:00 2.00 SURFAC WHDBOP NUND p 0.0 0.0 Nipple up casing head with FMC Rep antia::Chet k Data - GentDs). Gel (lOm) -t.GeL6pair4 Q-..HTHP 61* Deneity:temp :Solids, Corr Type Depth (*E1)." Dees (lb/dal) (Wet) Kt.Da:46 (eglOOft Nleft100.1 AMT. tiatiW gigt0))ICR Spud Mud 2,966.0 9.90 3.0 4.0 5.000 25.0 8.2 52.0 11.0 Spud Mud 2,966.0 9.90 3.0 4.0 5.000 25.0 8.2 52.0 11.0 Injection:Fluid .4 From Lease , - _, , :Destinettont = Vendor MallifeSt tiljntor-T4A • Cement Rinsate CD3-125 110.0 CD1-19 Cement Rinsate CD3-125 105.0 CD1-19 Cementing Fluids CD3-125 285.0 CD1-19 Drilling Mud WBM CD3-125 285.0 CD1-19 Drilling Mud WBM CD3-125 280.0 CD1-19 Drilling Mud WBM CD3-125 265.0 CD1-19 Pit Rinsate CD3-125 200.0 CD1-19 Weil biires: Wel !bore Name WelIbore APIIUWI CD3-125 .:-Section ; Size (Ih) - Top (ftKB) Act Ettni SURFAC 12 1/4 0.0 2,966.0 2/1/2011 CONDI 24 0.0 114.0 1/11/2011 1/11/2011 • Page 2/3 Report Printed: 2(11/2011 • 0 Security Level: AK Development .4 Daily Drilling Report _r, &WeIIs CD3 -125 CanacoPniuips t Report Number: 7 Rig: DOYON 141 Report Date: 2/5/2011 `Casing Strrngs - - 3 Stnng.OD Shing Wt - _ s Casing bescnptkri Run Date = -ttnj (Ibs/ft) a: Sfrtng Grade Se Depth (ftKB) ., =;Comment Surface 2/5/2011 9 5/8 40.00 L -80 2,953.3 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 1 Bowspring Centralizer on stop collar 10' below 1 the box of joint # 2 1 Bowspring centralizer on stop 10' above pin on joint # 3 Bowspring centralizer on joints # 4 -13. Then run Bowspring centralizer every other joint to surface - - °_.- . V .: , -x — :. T 14, Cement ;. �;� - -. � � �_ � � ,.. , � . ... -._ a; ..� F ,� .: ,�., .,.._ � e . Surface Casing Cement - Started (aZ 2/5 /2011 Type Welibore Cemented String Cement Evaluation Results casing CD3 - 125 Surface, 2,953.3ftKB Circulated 76 bbl cement to surface. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) Surface Casing Cement 3 450.0 °Fluid _ Amount(sacks) ...V(bbt) - Densityllb/gal). , Yield,(ft % sack) - _ - -Est. Top- (ft} ) -`.r (,:-:, ;Class - Lead Cement 326 262.0 10.50 4.49 0.0 2,451.0 Tail Cement 250 49.0 15.80 1.16 2,451.0 2,451.0 Page 3/3 Report Printed: 2/11 /2011 I ] 1 • Security Level: AK Development . .. . _ ..,_ Ellinialliirig Daily Drilling Report acWeills.':' CD3-125 =.„...; Report Number: 8 ConecoPhillips Rig: DOYON 141 Report Date: 2/6/2011 :AFE Type . ::: ''.':: :, -',: --,,.? , -; ,' Network/ID t4, --' -: z' -',- .-- : ;]TbtalAFE+SUp= :a 10296869 8,975,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-125 Development FIORD NECHELIK 4.56 8.0 0.00 2,966.0 2,966.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 46,972.08 379,829.74 997,695.62 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/30/2011 2/2/2011 30.31 31.10 -0.79 3/2/2011 Last Casing String Next casing OD (In) Next Casing Set Depth (ftKB) Surface, 2,953.3ftKB Ops and Depth (i Morning Report '24hr Forecast Rig Move F/ CD3-125 - T/CD3-199 Move Rig To CD3-199, Rig Up Last 24hr Summary N/U BOPE, Shell test, Set Tubing Wear Bushing, Rig Up and Run 3-1/2" Tubing kill string, Land tubing with 2 way check installed, Nipple down BOPE, Nipple up tree, Test tree, Displace and freeze protect well, Secure tree, Release Doyon 141 @ 24:00 General Remarks Weather • Head Count No accidents or incidents. Rig and Camp on High Line -23° Wind South @ 6 MPH, Wind Chill -39° 44.0 Guy Whitlock, Rig Supervisor Rig Supervisor Mark Brouillet, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Time Log if: VE'i!iii :t,l-r-Wz:Agi!:: .:::M::: .:=',g: ,''....'; R ..-_. Start : z c.0: ; DI.F _,:=.-- ,i,'E; :," i:= ;: , ..,:: ;:::::: -, €;:,f",,I:.: :::4::=1;;;',16::ZIL:,_::;',. , Time :- , ,-,z,:],...:-,::: , ,,, , ::,-,:_:::: z ::::i.:,:•_;'f;„! - ,:_: , : 7 pepth:Statt Depth Enct, rime Time ,ctitiay=!;: ,- -7,:,a l iV o - iii, , - , ,: , :g--::Atiroie l ito - dirii F! V(ftKB). W;PKE3kg. 00:00 02:30 2.50 SURFAC WHDBOP - NUND P 0.0 0.0 PJSM, Nipple Up BOPE and related equipment 02:30 03:30 1.00 SURFAC WHDBOP BOPE P 0.0 0.0 make up test joint, Rig up to shell test BOPE, Close annular pressure test BOP shell 250 psi low test 5 min, 2,000 psi high test 10 min. Test charted. Rig down from test 03:30 04:00 0.50 SURFAC RPCOMP NUND P 0.0 0.0 Set wear bushing for tubing run. 04:00 08:30 4.50 SURFAC RPCOMP PUTB P ' 0.0 2,800.0 Rig up and run 3-1/2" EUE Tubing 9.3 ppf L-80. Run order- WLEG, 89 joints i tubing, 4.5" X 3.5" crossover pup joint, 1 Pup on tubing hanger, Hanger. Calculated displacement 8.9 bbl's, Actual I Displacement 9.75 bbl's 08:30 09:30 1.00 SURFAC RPCOMP NUND 1 2,800.0 2,800.0 Rig up FMC wear bushing removal tool 1 and pull wear bushing 09:30 10:30 1.00 SURFAC RPCOMP HOSO P 2,800.0 2,833.0 Make up hanger and landing joint, land tubing. Install 2 way check. Tubing - landed @ 2,833' MD. Run in lock downs, Pull landing joint. 10:30 11:00 0.50 SURFAC DRILL PULD P - 2,833.0 0.0 Clear and clean rig floor 1 11:00 13:30 2.50 SURFAC WHDBOP NUND P . 0.0 0.0 PJSM, Nipple down BOPE, Nipple up Tree.( Fire drill held with 1.5 min response time) 13:30 14:30 1.00 SURFAC WHDBOP PRTS P 0.0 . 0.0 Test tubing adapter void to 5,000 psi for 10 min. Test tree with diesel 250 psi low, 5,000 psi high. Each test held for 5 min. Witnessed by Conoco rig Supervisor. 14:30 15:30 1.00 SURFAC WHDBOP NUND P 0.0 0.0 Pull 2 way check valve, Rig up to lines to displace. 15:30 17:00 1.50 SURFAC DRILL CIRC P 0.0 0.0 pump 25 bbl sweep and displace mud from well with fresh water. Pump water until returns clean. 17:00 18:30 1.50 SURFAC DRILL FRZP P 0.0 0.0 Freeze protect well. Pump 132 bbl's diesel down annulus take returns through tubing to pits. Latest BOP Test Data Page 1/2 Report Printed: 2/11/2011 • Security Level: AK Development Daily Drilling Report 6 &:Wefts - ` CD3 -125 Report Number: 8 ConocoPhillips Rig: DOYON 141 Report Date: 2/6/2011 Time Log _ - - Start _ End Dur Tfine a _ - - Depth Start -Deptt End Time Trme (hrs} Phase Op Code Actfvity Code . = P T X - Trbl Coda = Tr6 Class tft ) (ft�) _- __.Operation 18:30 19:30 1.00 SURFAC DRILL FRZP P 0.0 0.0 Rig up hose and U -tube diesel. 19:30 20:00 0.50 SURFAC WHDBOP NUND P 0.0 0.0 Set BPV, Secure well. 20:00 00:00 4.00 SURFAC DRILL DMOB P 0.0 0.0 Prep for rig move, Unhook Glycol lines, Blow down water and steam lines on sub. Off load all fluids, Blow down Power pack. Release rig @ 24:00 hrs. 1N�liboes s fix:` = . - .. Wellbore Name Welibore APUUWI CD3 -125 Section 5¢e On) - ActTop•(ttKB) , . _ Act Btm(ftK6)- '_ - = Start Date- - - , r; x End:Da SURFAC 12 1/4 0.0 2,966.0 2/1/2011 COND1 24 0.0 114.0 1/11/2011 1/11/2011 Tubing Strings e_, = ' 3 -1/2" Tbg Kill String set at 2,832.9ftKB on 2/6/2011 05:30 Tubing Description String Nominal OD (in) String Wt (ibs /ft) String Grade Set Depth MKS) 3 -1/2" Tbg Kill String 3 1/2 9.30 L -80 2,832.9 Page 2/2 Report Printed: 2/11 /2011 „, , ,,, ,/,/ / / ,0,,,, \ ///,./ 4 ,m_grai=z340".40)..7::, , 7/ , 0/ i f 1 , -;,,,e0 mei' - 4014*4::-- ‘ As, 4, II/ a se 00 44 v // f/ i , ,,,,,/, 0 4 / ,f opi _ •-• N.”, x il i o f.,, , i/f , . /4 , via 1-*2.48.• 4.k.,.:\ 1 1/4 \ )1 , i tat /,, ! ' , ! / ' , �� �, , ` ! 00 4 .. �.�. r t / • I'' +{ fl f ' . 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Ilk: / le /lb IV I I l f . 0 4• 0 ii e 40 , it , i , \ ma, Avaw -cb 4•wastav i 0. 00 ♦., . / fr 4 ii „ si. Ari su... ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh • Telephone 907 - 276 -1215 -16 z01 February 7 2011 =' Alaska Oil and Gas Conservation Commission csg. r . .Arts. 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3 -122 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3 -122 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3 -122 approximately March 1st, 2011. Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9 -5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within % mile radius at AOGCC: CD3 -110, CD3 -106, CD3 -111, CD3 -112, CD3 - 113, CD3 -114, CD3 -115, CD3 -118, CD3 -117, CD3 -121 • 13. Information regarding remaining wells within % mile radius included in sundry package: CD3 -123 and CD3- • 125 14. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (14.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (16.3 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Nina Anderson at 265 -6403 or Liz Galiunas can also be reached by calling 265 -6247. Sincerely, Ryan Robertson Sharon Allsup -Drake ATO -1530 Drilling Engineer cc: CD3 -123 and CD3 -125 well files Chip Alvord ATO -1570 • • Note to File CD3 -122 (209 -253 311 -035) Colville River Unit (Fiord) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD3 -122). -- 9 5/8" Surface casing was cemented to surface successfully with good returns throughout. No problems were reported. Approximately 58 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 90% XS of the calculated hole volume. - - On the initial leak off test (LOT) for the surface casing shoe dated 1/16/10 , the pressure slope rises smoothly to -15.5 EMW and continues at a slightly shallower slope to 16.3 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 14.1 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Good returns were noted and the casing was reciprocated. Qannik zone was covered in the second stage (40bbls) of the cement job. TOC for the second stage is estimated to be at 4200' md. - -An initial injectivity test ( LOT #1) down 7" X 9 5/8" annulus was conducted on 1/23/10. Pressure steadily increases until the break at 14.3 EMW. The pressure increased with additional pumping to 15 ppg EMW. During the observation period, the pressure declined to 13.0 ppg EMW. - - A second LOT of test was conducted on 1 -27 -11 to recheck the pressures and OA status to pumping. The data was suspect so the commission requested another LOT . The results of LOT #3 (done 2- 28 -11) are as follows: Pressure steadily increases until the break at 14.0 EMW. The pressure increased with additional pumping to 15.1 ppg EMW and remains stable here. During the observation period, the pressure declined to 13.8 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity - -There are several wells within 1 mile radius of CD3 -122. The surface shoe of CD3 -112 is closest, about 308' distant. CD3 -123 is 310' and CD3 -114 is 405' distant. AD was approved for CD3 -112 in 2007. There are no identified issues with any of the proximal wells. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. 0 -- - --- - .5 .------ j Guy chwartz Sr. Petroleum Engineer AOGCC February 28, 2011 G:\AOGCC \Common \tommaunder \Well Information\By Subject\Annular Disposal \110228_CD3- 122.doc • Note to File CRU CD3 -122 (PTD 2091530) February 23, 2011 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3 -122 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the 9 -5/8" x 7" annulus within well CD3 -122. Recommendation Approve Conoco Phillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at about 2,685' measured depth (- 2,436' true vertical depth subsea, or "TVDSS "),' near the base of a 400 -foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 125' from the wellbore. Discussion CPAI's application was reviewed along with records and well logs from Colville River Unit (CRU) wells CD3 -108, CD3 -114, and the Nechelik 1 exploratory well. An index map is provided in Figure 1, below. The CD3 -122 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, Alaska (ConocoPhillips) the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3 -122 that extends downward from the 9 -5/8" surface casing shoe, which is set at about 2,685' (- 2,436' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 7,494'I( Nnre (- 6,235' TVDSS). This annulus lies within Section 5 of T12N, R5E, Umiat Meridian (see Figure 1). p C'.' The annulus is located more than 2 miles from the current external boundary of the CRU. �. Yzoo 2 ' All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness, unless otherwise noted. For clarity, depths expressed as true vertical depth below sea level Z4' h will be preceded by a minus sign and followed by the suffix "TVDSS." 2 Top of cement estimate was determined by G. Schwartz, AOGCC, and is recorded in AOGCC spreadsheet \ \Doaancoacfps01\ Shared \ AOGCC \ Common \tommaunder \aa2009 0712_Working -Well Cement Cun ent.x1s worksheet MIT II, PTD 209 -153, column titled 30% Excess TOC. • • CD3 -122 February 23, 2011 Note to File Page 2 of 5 The section of annulus in CD3 -122 that will most likely accept the injected waste fluids (likely receptor interval) is a portion of the Seabee formation that extends from about 2,735' to 2,803' 1 (- 2,475' and - 2,529' TVDSS; see Figure 2, below). This 54 -foot thick interval contains numerous 1- to a- foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 20 feet. On the well log from CD3 -114, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9 -5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9 -5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). The 9 -5/8" surface casing shoe lies near the base of a 480 -foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 55 -foot thick interval of siltstone that is also continuous throughout the area. This interval, which lies between about 2,953 and 3,023(- 2,648' and - 2,703' TVDSS), and two similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. __ _ _._ _. ,_ _._. ___.- ',I � ...... 0 CD ... _. .____ \/1O7 / CD3 113 I O CD3 -114 1 \\ 0 rD3 -115 \ #CD33Z r o3 -tte , CRU CD3 -122 n CD3{307 f ' _._ Annulus _... �..._. { C C 117 orr. � D3 -1F4 I GLI D 1A \ 1I te r'; 3 CD3 - 14 M ost Likely Receptor \ Interval _�., " Area of Review (highlighted with red) 11 -12 (shaded blue) 1 ►: l 010,11 i \ _ _ _ CD -122 A Surface casing shoe gg� Cement top` 'J C lOk@y -127 Figure 1. Index Map (The path of the cross - section shown on Figure 3 is depicted by the magenta - colored Line) In vicinity of Drill Site CD3, the base of permafrost occurs at about - 1,200' TVDSS, which is about 1,275' shallower than the top of the likely receptor interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. . • • CD3 - 122 February 23, 2011 Note to File Page 3 of 5 Correlation Depth Resis Porosity OR <MD ResD(RPD) RHOB -10 API 24C 3.2 OHMM 2001. GfCC 2.65 'Sand - Silt - Shale' TVDSS> ResM(RPM) ow Pm. 3.2 OHMM 211 SP(N /A) TVD ResS(RPS) NPOR -100 10C 3. OHMM 2000 C Upper <M D DTCP(N/A) Confining 170 7C Strata —► 7 UU - ;qii Most Likely -{ Receptor 2800 Interval for 250u Disposed 2900 Fluids 2600 3000 -2600 Lower 3100 ' 700 Confining —► -2700 Strata 3200 1300 3300 -2800 3400 ' gnu -2900 3500 ,000 - 3600 -3000 ;100 3700 -3100 3800 3900 4000 - uu 4100 4200 4300 Figure 2. CD3 -122 Well Log Displaying Affected Intervals • • . CD3 -122 February 23, 2011 Note to File Page 4 of 5 1811490 2070330 2091530 2050330 501032002000 501032054400 501032060900 501032050700 SW 11szo n ao5 n 3a6s n NE SOHIO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 COLVILLE RIV UNIT CD3 -114 CRU CD3 -122 COLVILLE RIV UNIT CD3 -108 2340 FSL 814 FWL 3960 FNL 2703 FEL 3998 FNL 1088 FEL 1349 FSL 816 FEL TWP• 12 N - Range: 5 E - Sec. 18 TWP: 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 .... -. ®it'd 'i MIMI ® 0 ii woo . 1000 . T - Upper _ t' — • - _ 9-5/8" Casing Shoe Confining _t___ - - 500 . _ - _ _. r Strata 500 Likely 1 Receptor Interval . 1 - 0 - R Lower : _ "° 0 if Confinin ... fr ,.., _ r • ... - Strata #' 500 • - m _ `t -500 - is s — s - - ."° „ "'" 4- Fi -1000 3 - .m 4 -1000 - =0 i A k Ta=18915 -" i --I: , .., _ TD =18601 TD =10018 TD =15364 Figure 3. Stratigraphic Cross - section from Nechelik 1 TO CRU CD3 -108 Nearby well CD3 -114 is the only well that was mud logged on Drill Site CD3. In CD3 -114, methane was first encountered at about 1,115' (- 1,050' TVDSS). So, the entire proposed disposal zone likely contains some gas. The shallowest oil show encountered in well CD3 -114 was observed at 6,050' (- 4,413' TVDSS), about 1,830' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of "trace" quality. This instance is judged to represent only small amounts of residual (non- mobile) oil. So, at Drill Site CD3 the likely receptor interval does not contain potentially commercial quantities of oil or gas. 1 10 • CD3 -122 February 23, 2011 Note to File Page 5 of 5 The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3 -122 that will be affected by the proposed annular disposal operations. There are about 15' of porous sandy siltstone and silty sandstone beds within the likely receptor interval, according to a count using the gamma ray curve from CD3 -122. Neutron and density porosity well logs were recorded across the proposed disposal interval in nearby well CD3 -108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values and assuming piston -like displacement of native formation fluids around the wellbore, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 125' from the wellbore, as indicated in the chart below. Injected Fluid vs Affected Radial Distance CD3 -122 Wellbore (assumes 15' aggregate injection zone thickness and 28% porosity) 300 1 - 250 0 0 a d 200 E 0 0 U co 150 _ 0 100 re d 0 m < 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3 -122 Annular Disposal Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. I rec• mend approval of this annular disposal project. Steve Davies .u�e Senior Petroleum Geologist / / v sr . • O /e fib• iffrivrotA E NGt/0ot Page 1 of 1 • Schwartz, Guy L (DOA) From: Anderson, Nina M [ Nina .Anderson @conocophillips.com] Sent: Saturday, February 26, 2011 5:17 PM To: Schwartz, Guy L (DOA) Cc: Galiunas, Elizabeth C; Robertson, Ryan G Subject: RE: CD3 -122 AD permit ( PTD 209 -153) Attachments: CD3 -122 OA LOT 01 -23 -10 .xis Guy — I've requested a second injectivity test to be done this weekend on CD3 -122 for annular disposal permitting. I agree the data does look questionable. Once the data is reviewed I'll send an updated form. The 14.3 ppg EMW that was referred to in the cover letter is from the original LOT pump in from last year. In the past, we have used the most recent injectivity test data for all documentation in the permit. For clarification, I've attached the original 14.3 ppg EMW test from 01/23/10. This test is more typical of what we see with our LOT than the re -test that was performed this year. It has a smoother trend than the double slope change observed on 1/27/2011. From this, it can be seen that the possibility of channeling is minimal. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 229 -4008 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, February 25, 2011 4:39 PM To: Anderson, Nina M Cc: Galiunas, Elizabeth C Subject: CD3 -122 AD permit ( PTD 209 -153) Nina, In reviewing the AD permit t have some questions... The cover letter states a LOT of 14.3 EMW for the pumpin- test was done for this well at some point. I cannot find any documentation for that in the paperwork submitted. I reviewed the LOT ( pump -in) done on 1/27/2011 and it seems to be suspect I am not sure I agree with the 15.4 EMW leak -off pick as shown on this document. 1 may require another pump -in test to be done on this annulus to verify injection pressures will stay below the safe limit of 16.3 ppg EMW of the original shoe test done on 1/1612010. Give me a call to discuss when you have a minute. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 2/28/2011 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 3, 2011 Commissioner Dan Seamount Alaska Oil & Gas Commission C1 TT 333 West 7 Avenue, Suite 100 FEB 0 4 2019 • Anchorage, AK 99501 T4x r`ie G : COfhS. Cl`I., 114iOn n i Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each:conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field CD3 Pad Date y312011 Corrosion Initial top of Vol. of cement Final top of Cement top o" Corrosion inhibitor/ ce ment date inhibitor sealant API # PTD # cement • um • _ • �� Well Name bbls ft 1/31/2011 NA 16" NSA 1/31/2011 CD3 -1 501032050 501032050 0000 2 90000 20 50410 50410 4" NA 6" NA ® 1/312011 CD3 -1100 4 16" NA 1/312011 CD3-112 50103205270000 2060320 5" NA 14" NSA 1/31/2011 CD3 -1 501032061 501032061 20000 21 00220 5" NA 32" NA ® 1/31/2011 CD3 -12 092091 ' 32" " NA 74" NA ® 1/31/2011 CD3 -124 50103206120000 17 " NA 17" 1/312011 CD3-301A 4 50103205130100 2160170 NA 15" 1/312011 CD3 -30 50103205430100 2 9" NA 16" NA 1/31/2011 CD3-302A 50103205220100 2100350 5 CD3 - 304 50103205980000 2090280 18" 18" -= I . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil is • 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: �P_J� 5. Date Comp., Susp., j , � l 6 12. Permit to Drill Number: p ConocoPhillips Alaska, Inc. or Aband.: February 20195. 209 - 1530 / . 3. Address: 6. Date Spudded: 2v-/`6'3. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 12, 2010 ' 50 103 - 20609 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1282' FSL, 1088' FEL, Sec. 5, T12N, R5E, UM • January 31, 2010 • CD3 - 122 ' Top of Productive Horizon: 8. KB (ft above MSL): 48.7' RKB . 15. Field /Pool(s): 865' FSL, 476' FWL, Sec. 5, T12N, R5E, UM GL (ft above MSL): 12.6' AMSL - Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1077' FSL, 1012' FEL, Sec. 8, T12N, R5E, UM 15399' MD / 7029' TVD Fiord Oil Pool ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 387955 • y - 6003780 • Zone 4 • 15409' MD / 7029' TVD • ADL 372105 • TPI: x - 384235 y - 6003419 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 387965 y - 5998294 Zone 4 2198' MD / 2097' TVD LAS 2112 18. Directional Survey: Yes Q 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) approx. 1500' 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 TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# I•1-40 37' 114' 37' 114' 24" pre - installed 9 -5/8" 40# L -80 37' 2685' 37' 2485' 12.25" 360 sx AS Lite, 140 sx Class G 7" 26# L -80 37' 9130' 37' 6958' 8.75" 273 sx Class G, 187 sx Class G 3.5" 9.3# L -80 8720' 15399' 6928' 7029' 6.125" liner 24. Open to production or injection? Yes ❑ No 0 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" x 3.5" 134' x 8766' 8720' gravel pack screens 9787'- 14597' MD 6968' -7037' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10441'- 14594' 1 MM JO of 16/30 whitesand As s•g• 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook - up Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No is Sidewall Cores Acquired? Yes ❑ No 0 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 RECEIVED __ 1 eo iviFL - ic i NONE ! �,'E j l d MAR 0 4 2010 I - .. lake Oil & Bas Cans. Comrrgssion Anchorage Form 10-407 Revised 121 09 CONTINUED ON REVERSE Submit original only li9DMS MAR 05 2010 i 122 3.0 • to , .3'.=(../z, • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1527' 1500' needed, and submit detailed test information per 20 AAC 25.071. C30 2683' 2483' C20 3167' 2864' K -3 4453' 3876' K -2 4666' 4045' Nanuq 7003' 5893' K -1 8120' 6714' Kuparuk 8196' 6755' Kuparuk C 8287' 6800' Nuiqsuit 8296' 6801' Nechelik 9043' 6953' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, Final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson @ 265 - 6318 Printed Name /� Alvord Title: Alaska Drilling Manager /, iv Signature l Phone 265 - 6120 Date Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 -122 C©nocaPhillips =1 T.oriok Well Attributes Max Angle & MD TD Aai6E1,1rx; Wellbore APUUWI (Field Name Well Status Inc! ( °) IMD (ftKB) Act Btm (ftKB) CrxY Cd^ulkds 501032060900 FIORD NECHELIK PROD 93.82 15,246.95 15,409.0 Comment H2S (ppm) Dale IAnnotation End Date KB - Grd (ft) Rig Release Date ,.. Well Gent l0RL 0,. AL ' CD31 2128/26/10324160 PM Last 1 T . a TROP Last WOE I . 40 90 2/5/2010 Schemelic A a Annotation Depth (866) I End Dale (Annotation 'Last Mod. - . End Date Tubing Hanger - g Rev Reason: Reset FRAC SLV, GLV C /0,, Pull Gauges I Imosbor 2/28/2010 Casing Strings Casing Description String 0... String ID Top (f11(8) Set Depth (f Set Depth (TVD) .. String Wt... ) Str g ,String Top Thrd CONDUCTOR 24" 16 15 250 37 0 114.0 114.0 62.50 0 -40 Welded - Insulated r- ; [pip - ._.� I Casing Description String 0... String ID Top (ftKB) Set Depth (f.. Set Depth (TVD) .. String Wt... String ... String Top Thrd 24 Insulated, SURFACE 9 5/8 8 835 36.1 2,685 .1 2,485.0 40.00 L - 80 BTC - m 37 -114 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... Sting ... String Top Thrd INTERMEDIATE 7 6.276 33.6 9,130.0 6,957 8 26.00 L - 80 BTC - m SAFETY Z V8 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) .. String Wt... String .. String Top Thrd FRAC SLV , LINER . - LINER 31/2 . 1' 8,720.0 15,399.0 7,0293 9.30 L80 SLHT 2,198 t' „ - . ,. Liner Details Top Depth I V (TVD) Top Inc! Nomi... SURFACE, J \ Top (ftKB) (ftKB) ( °) item D ription Comment I ID (in) 36 - 2,685 8,720.0 6,928.8 80.71 PACKER Baker 5" x 7" ZXP liner top packer 1 4380 GAS 3875 3111= 8,740.6 6931.4 81.14 NIPPLE RS Nipple 4250 ABC I 8,743.5 6,931.9 8129 HANGER Baker 5" x 7" Flexlock liner hanger 4.430 8,7526 6,933.5 81.76 SBE Baker Seal bore extension 80-40 4.000 8,771.7 6,936.3 82.75 X0 - Enlarging Crossover 5" BTC x 3 -1/2" SLHT 2.950 GAS LIFT, 9,786.5 6,968.0 8943 Gravel Packs Reslink 316E 12 guage wirewrap screen w/ Resman Tracer 2.992 I I I 6,650 9,801.5 6964.3 86.29 SLEEVE Baker Ball Actuated Sleeve 4.35" OD x 2.15" ID (2.25" Ball) 2.150 9,809.6 6,965.0 86.45 Gravel Packs Reslink 316E 12 guage wirewrap screen w/ Resman Tracer 2.992 GAS LIFT. .i'- - ._. 8,326 ' " 10 423.7 6,983.1 86.68 Swell Packer TAM Swell Packer 3 -1/2" SLHT 2.992 10 817.5 6,989.1 90.04 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 NIPPLE, 8,406 - _ __.. ___ ___. _. ____ 10,832.6 6,989.1 89.98 SLEEVE Baker Ball Actuated Sleeve 4.35" OD x 2.025' ID (2.125" Ball) 2.025 LOCATOR, c 10,840.7 6,989.1 89.95 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 8,728 Spacer Tube, _ - 11,295.3 6,989.4 91.11 Swell Packer TAM Swell Packer 3 - 1/2" SLHT 2.992 8,730 Spacer a be, ... _. f" 11,723.0 6,989.5 89.75 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 .4'7 11,738.1 6,989.6 8977 SLEEVE Baker Ball Actuated Sleeve 4.35" OD x 1.90" ID (2.00" Ball) 1.900 Spacer Tube. _, 8,745 11,746.3 6989.7 89.78 Gravel Pucks Reslink 316E 12 guage wirewrap screen w/ Resman Tracer 2.992 SEAL ASSY, e,755 12,199.5 6,990.0 89.72 Swell Packer TAM Swell Packer 3-1/2" SLHT 2.992 12,626.2 0996.6 90.37 Gravel Packs Reslink 316E 12 guage wirewrap screen w/ Resman Tracer 2.992 12,641.3 6.996.4 90.22 SLEEVE Baker Ball Actuated Sleeve 4.35" OD 8 1.775" ID (1 875" Ball) 1.775 12,649.4 6,996.4 90.14 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 13,108.9 6,998.5 89.79 Swell Packer TAM Swell Packer 3 -1/2" SLHT 2.992 1 i NTERMEDIATE, _... _.. _ 34 -s,13o 13,505.1 7, 009.4 88.36 Gravel Packs Reslink 316E 12 guage wirewrap screen w/ Resman Tracer 2.992 13,520.2, 7,009.8 88.29 SLEEVE Baker Ball Actuated Sleeve 4.35" OD x 1.650" ID (1.75" Ball) 1.650 13,528.4 7,008.7 8721 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 13,862.7 7,019.2 89.12 Swell Packer TAM Swell Packer 3 -1/2" SLHT 2.992 14,573.3 7,037.9 89.74 Gravel Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 14,588.5. 7,037.2 88.631 SLEE/, E Baker Ball Actuated Sleeve 4 3 5 0 0 5 1 1 525" ID (1 625" Ball) 1.525 14. b96.6 /.0 - - i/ 4 88 64 Grave Packs Reslink 316L 12 guage wirewrap screen w/ Resman Tracer 2.992 Tubing Strings Tubing Description String 0 Sir p( ) I Depth (... Depth (TVD) String St. - (String Top Thrd 4 ID _ . Top ftKB Set De th f Set De th TVD St 'n Wt. -. 'String I UBING - 1/2 : 1 30 S 8.766.1 6,935.5 9 30 I L-80 1 EUE -m Completion Details Top Depth (TVD) Top Intl Nomi... Top ) p Comment To ftKB ( K ) ( °) Item Description ID (in) 132.6 132.6 1.05 X0 - Reducing Crossover 4-1/2" 12.6 ppf L-80 box x 3 -1/2" 9.3 ppf L-80 pin 2.992 2,197.9 2,096.9 33.34 SAFE I Y VLV 3 -1/2" Camco TRMAXX -5E SSSV w/ 2.813" X profile (2.813" profile) 2.812 8,406.1 6,844.2 68.53 NIPPLE Camco D Nipple (2.75" min ID) 2.750 8,728.3 6929.0 8051 LOCATOR Locator 2.990 8,729.5 6,929.3 80.57 Spacer Tube Baker GBH- 2280 -40 Spacer tube 3.000 8,7345 6,9353 8053 Spacer Tube Baker GBH-22 80-40 Spacer tube 3.000 8,744.6 6,932.1 81.35, Spacer T It be Baker GBH-22 80-40 Spacer tube 3.000 5,754.7 6,933.8 81 87 SEPL. 66-101/11 22 80 -00 Bonded Seal assembly 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc -) FRAC. 10.441 Top Depth (TVD) Top Incl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 2,198 2,096.8 33.34 FRAC SLV FRAC SLEEVE FOR UPCOMING FRAC 2/27/2010 Mandrel Details w a Top Depth Top I Port (TVD) Inc' OD Valve Latch Sian ITRO Run Stn Top (HKB)__.. (ftKB) 0) Make Model (gin) Sery TYR. TYPn (In) (psi) Run Date Com... 1 3,874.6 3,421.5 37.15 Camco KBMG 1 GAS LIE I DMY BK -5 0.000 0.0 2/27/2010 2 6,650.5 5,611.2 38.12 Camco KBMG 1 GAS LIE I GLV BK -5 0.188 1,677.0 2/27/2010 3 8,325.8 6,812.9 65.82 Camco KBMG 1 GAS LIFT OV BK -5 0.250 0.0 2/27/2010 LINER, 8,720 - 15.399 \ TD, 15,409 r - 0 WNS CD3 -122 ConocoPhillips �> AU<- 2ka. i ,J - KB -Grd (66) Rig Release Date Weu Cor19g:_NOR12PNiAL x ,093 -t 27, 2/2W2010 $ Ed.� 69 _- _ l -.. 40 90 .._. 2!5/2010 - Tu iing Nan9er, ,R.;. _ _ �k Stimulations & Treatments - ,- ,.w=.a. x _ _ s., 0 _ .4 r-, b ' �;: Bolt m _ M n Top Mao Bhn Top Depth Depth -„ - - Depth Depth (TVD) /360) .. (RKB) (RKB) (flKB) (RKB) Type Date Comment 24. 0reu1[4 10,441.0 14,594.0 6,984.1 7 037.3 FRAC 2/25/2010 5 -STAGE FRAC - PUMPED A TOTAL OF 1,059,078 37 -114 LBS OF 16/30 COLORADO WHITESAND PLACED BEHIND PIPE. FRAC PUMPED TO 107% DESIGN. SAFETY oiv, _ (SIP = 2101 PSI, 15 MIN WHP = 1690 PSI. FREEZE 2,166 \ • !,. PROTECTED WELL WITH 35 BBL OF DIESEL. FRAC SLY,- _ 2,198 Notes: General &Safety _ , __ �: End Date -- "— Annotation 2/19/2010 NOTE- VIEW SCIik IA'IC w /Alaska Schematic9.CREV SURFACE, _� t -- 36 -2,885 GAS LIFT _.. 3,875 ''.�„ GASLIFT,_ _ -. • _. 8.850, ,,: GAS LIFT,_"' 8,32fi NIPPLE, 8,406 - 1 ^'•;.- LOCATOR, 6,728 Spacer Tube, 8,730 Spacer 6,735 .__ 8,735 - -- _ r -- SPacer Tube, t`— -`ti 8,745 SEAL A ,755 -_ 8,755 NTERMEDIATE,__.. i 34 -9,130 FRAC, 10,441 LINER, 8,720.15,399 �.._ TD, 15,409 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom OPERATOR: Conoco Phillips Alaska FIELD / UNIT / PAD: Alipne DATE: 02/04/10 OPERATOR REP: D. Burley / J. Browning AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3 -122 Type lnj. ND 6,929' Tubing 2,000 2,600 2,600 2,600 Interval P.T.D. 209 -1530 Type test P Test psi 3500 Casing 500 3,537 3,512 3,503 P/F P Notes: OA 0 0 0 0 Well Type lnj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA I TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waist M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Waistewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CD3 -122 xls ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -122 501032060900 Sperry Drilling Services Definitive Survey Report 08 February, 2010 'w HALLWBURTON Sperry Drilling Services 0 0 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) . Site: CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Well: CD3 -122 North Reference: True Weltbore: CD3 -122 Survey Calculation Method: Minimum Curvature Design: CD3 -122 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3 -122 Well Position +N / -S 0.00 ft Northing: 6,003,779.80 ft • Latitude: 70° 25' 9.350 N +E / -W 0.00 ft Easting: 387,954.76 ft - Longitude: 150° 54' 45.983 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft • Welibore CD3 -122 Magnetics Model Name Sample Date Declination Dip-Angle Field Strength (°) el (nT) BGGM2007 1/13/2010 21.27 80.78 57,639 Design CD3 -122 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.10 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) {°) . 36.10 0.00 0.00 143.00 Survey Program Date . From To (ft) (ft) Survey (Weilbore) Tool Name Description. Survey Date 81.00 727.00 CD3 -122 Gyro (CD3 -122) GYD -GC -SS Gyrodata gyro single shots 1/13/2010 t 814.18 15,342.39 CD3 -122 MWD (CD3 -122) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 1/13/2010 t Survey Map Map . Vertical MD Inc Azi TVD TVDSS +N / -S +E/-W Northing Easting DLS Section (ft) ( °) r (ft) -(ft) (ft) (ft) (ft) (ft) (° /400') (ft) Survey Tool Name 36.10 0.00 0.00 36.10 -12.60 0.00 0.00 6,003,779.80 387,954.76 0.00 0.00 UNDEFINED 81.00 0.63 286.52 81.00 32.30 0.07 -0.24 6,003,779.87 387,954.52 1.40 -0.20 GYD -GC -SS (1) 173.00 0.93 287.57 172.99 124.29 0.44 -1.43 6,003,780.26 387,953.33 0.33 -1.21 GYD -GC -SS (1) 265.00 0.66 296.08 264.98 216.28 0.90 -2.62 6,003,780.74 387,952.15 0.32 -2.29 GYD -GC -SS (1) 358.00 0.34 268.87 357.98 309.28 1.13 -3.38 6,003,780.98 387,951.40 0.42 -2.93 GYD -GC -SS (1) 450.00 1.01 308.08 449.97 401.27 1.62 -4.29 6,003,781.49 387,950.49 0.84 -3.88 GYD -GC -SS (1) 542.00 2.13 317.56 541.94 493.24 3.38 -6.08 6,003,783.28 387,948.73 1.25 -6.36 GYD -GC -SS (1) 636.00 3.17 328.22 635.83 587.13 6.88 -8.63 6,003,786.81 387,946.23 1.22 -10.69 GYD -GC -SS (1) 727.00 5.96 335.00 726.54 677.84 13.30 -11.95 6,003,793.28 387,943.01 3.12 -17.82 GYD -GC -SS (1) 814.18 8.39 330.61 813.03 764.33 22.95 -16.99 6,003,803.00 387,938.12 2.86 -28.55 MWD +IFR- AK- CAZ -SC (2) 858.45 9.46 325.93 856.76 808.06 28.78 -20.61 6,003,808.88 387,934.59 2.92 -35.39 MWD +IFR- AK- CAZ -SC (2) 952.35 11.81 314.47 949.05 900.35 41.91 -31.79 6,003,822.17 387,923.60 3.36 -52.60 MWD +IFR- AK- CAZ -SC (2) 1,047.03 12.53 314.16 1,041.61 992.91 55.85 -46.07 6,003,836.33 387,909.53 0.76 -72.33 MWD +IFR- AK- CAZ -SC (2) 2/8/2010 9 :58 :51AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Well: CD3 -122 North Reference: True Wel!bore: CD3 -122 Survey Calculation Meth od: Minimum Curvature Design: CD3 -122 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NF -S +Et -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft), (ft) (ft) (ft) (ft) (°I1t10') _ (ft) Survey Tool Name 1,140.63 13.41 312.33 1,132.82 1,084.12 70.23 -61.38 6,003,850.94 387,894.44 1.04 -93.03 MWD +IFR- AK- CAZ -SC(2) 1,238.06 15.40 315.65 1,227.18 1,178.48 87.09 -78.78 6,003,868.06 387,877.30 2.21 - 116.97 MWD +IFR- AK- CAZ -SC (2) 1,333.50 18.78 312.75 1,318.39 1,269.69 106.59 -98.93 6,003,887.85 387,857.45 3.65 - 144.66 MWD +IFR- AK- CAZ -SC (2) 1,428.71 21.81 305.38 1,407.70 1,359.00 127.24 - 124.61 6,003,908.88 387,832.08 4.16 - 176.61 MWD +IFR- AK- CAZ -SC (2) 1,523.86 23.32 297.22 1,495.58 1,446.88 146.09 - 155.78 6,003,928.20 387,801.20 3.65 - 210.43 MWD +IFR- AK- CAZ -SC (2) 1,618.88 24.00 294.78 1,582.62 1,533.92 162.80 - 190.05 6,003,945.42 387,767.19 1.25 - 244.39 MWD +IFR- AK- CAZ -SC (2) 1,714.01 25.16 292.18 1,669.13 1,620.43 178.54 - 226.34 6,003,961.70 387,731.14 1.67 - 278.81 MWD +IFR- AK- CAZ -SC (2) 1,809.21 24.37 290.86 1,755.57 1,706.87 193.17 - 263.44 6,003,976.89 387,694.27 1.01 - 312.82 MWD +IFR- AK- CAZ -SC (2) 1,904.56 25.02 290.71 1,842.20 1,793.50 207.31 - 300.68 6,003,991.58 387,657.25 0.68 - 346.52 MWD +IFR- AK- CAZ -SC (2) 1,999.47 28.38 289.44 1,926.98 1,878.28 221.92 - 340.74 6,004,006.79 387,617.42 3.59 - 382.29 MWD +IFR- AK- CAZ -SC (2) 2,094.62 31.22 288.64 2,009.54 1,960.84 237.33 - 385.44 6,004,022.87 387,572.96 3.01 - 421.50 MWD +IFR- AK- CAZ -SC (2) 2,189.38 33.17 286.94 2,089.73 2,041.03 252.73 - 433.51 6,004,038.99 387,525.13 2.27 - 462.74 MWD +IFR- AK- CAZ -SC (2) 2,283.29 35.05 286.63 2,167.48 2,118.78 267.94 - 483.93 6,004,054.95 387,474.95 2.01 - 505.22 MWD +IFR- AK- CAZ -SC (2) 2,379.65 37.79 285.97 2,245.01 2,196.31 283.98 - 538.83 6,004,071.81 387,420.29 2.87 - 551.08 MWD +IFR- AK- CAZ -SC (2) 2,474.73 38.60 286.09 2,319.74 2,271.04 300.22 - 595.34 6,004,088.89 387,364.04 0.86 - 598.05 MWD +IFR- AK- CAZ -SC (2) 2,570.06 38.21 285.12 2,394.44 2,345.74 316.15 - 652.37 6,004,105.68 387,307.26 0.75 - 645.10 MWD +IFR- AK- CAZ -SC (2) 2,649.05 38.23 284.82 2,456.50 2,407.80 328.77 - 699.59 6,004,119.01 387,260.25 0.24 - 683.59 MWD +IFR- AK- CAZ -SC (2) 2,736.27 37.99 284.70 2,525.12 2,476.42 342.49 - 751.64 6,004,133.50 387,208.41 0.29 - 725.87 MWD +IFR- AK- CAZ -SC (2) 2,779.40 37.62 284.29 2,559.20 2,510.50 349.11 - 777.24 6,004,140.50 387,182.92 1.04 - 746.56 MWD +IFR- AK- CAZ -SC (2) 2,874.21 37.39 285.98 2,634.42 2,585.72 364.17 - 832.95 6,004,156.40 387,127.44 1.11 - 792.13 MWD +IFR- AK- CAZ -SC (2) 2,968.70 37.70 285.62 2,709.34 2,660.64 379.85 - 888.36 6,004,172.91 387,072.28 0.40 - 837.99 MWD +IFR- AK- CAZ -SC (2) 3,064.72 39.02 285.78 2,784.63 2,735.93 395.98 - 945.72 6,004,189.89 387,015.17 1.38 - 885.39 MWD +IFR- AK- CAZ -SC (2) 3,159.69 38.86 285.28 2,858.49 2,809.79 411.96 - 1,003.23 6,004,206.73 386,957.91 0.37 - 932.76 MWD +IFR- AK- CAZ -SC (2) 3,254.89 38.44 285.14 2,932.84 2,884.14 427.56 - 1,060.61 6,004,223.19 386,900.78 0.45 - 979.75 MWD +IFR- AK- CAZ -SC (2) 3,350.16 38.00 284.87 3,007.69 2,958.99 442.82 - 1,117.54 6,004,239.30 386,844.09 0.49 - 1,026.20 MWD +IFR- AK- CAZ -SC (2) 3,445.37 39.17 285.95 3,082.11 3,033.41 458.60 - 1,174.78 6,004,255.95 386,787.09 1.42 - 1,073.26 MWD +IFR- AK- CAZ -SC (2) 3,540.91 38.68 285.05 3,156.44 3,107.74 474.65 - 1,232.62 6,004,272.85 386,729.50 0.78 - 1,120.88 MWD +IFR- AK- CAZ -SC (2) 3,635.45 37.65 284.84 3,230.77 3,182.07 489.71 - 1,289.06 6,004,288.76 386,673.30 1.10 - 1,166.88 MWD +IFR- AK- CAZ -SC (2) 3,731.17 36.86 284.42 3,306.96 3,258.26 504.35 - 1,345.13 6,004,304.24 386,617.47 0.87 - 1,212.31 MWD +IFR- AK- CAZ -SC (2) 3,823.24 37.13 283.07 3,380.50 3,331.80 517.51 - 1,398.94 6,004,318.21 386,563.86 0.93 - 1,255.21 MWD +IFR- AK- CAZ -SC (2) 3,921.02 37.17 284.46 3,458.43 3,409.73 531.56 - 1,456.29 6,004,333.11 386,506.73 0.86 - 1,300.94 MWD +IFR- AK- CAZ -SC (2) 4,016.94 37.97 284.86 3,534.46 3,485.76 546.37 - 1,512.87 6,004,348.76 386,450.38 0.87 - 1,346.82 MWD +IFR- AK- CAZ -SC (2) 4,111.65 38.34 284.38 3,608.93 3,560.23 561.13 - 1,569.49 6,004,364.38 386,394.00 0.50 - 1,392.68 MWD +IFR- AK- CAZ -SC (2) 4,205.76 37.86 283.82 3,682.99 3,634.29 575.28 - 1,625.81 6,004,379.37 386,337.91 0.63 - 1,437.88 MWD +IFR- AK- CAZ -SC (2) 4,301.92 39.10 286.15 3,758.27 3,709.57 590.77 - 1,683.59 6,004,395.72 386,280.36 1.98 - 1,485.02 MWD +IFR- AK- CAZ -SC (2) 4,397.00 38.70 286.15 3,832.27 3,783.57 607.37 - 1,740.94 6,004,413.18 386,223.27 0.42 - 1,532.80 MWD +IFR- AK- CAZ -SC (2) 4,492.39 37.94 286.23 3,907.11 3,858.41 623.86 - 1,797.75 6,004,430.52 386,166.73 0.80 - 1,580.15 MWD +IFR- AK- CAZ -SC(2) 4,586.62 37.05 285.00 3,981.87 3,933.17 639.31 - 1,852.98 6,004,446.79 386,111.74 1.23 - 1,625.73 MWD +IFR- AK- CAZ -SC (2) 4,681.89 37.38 284.71 4,057.74 4,009.04 654.08 - 1,908.68 6,004,462.40 386,056.28 0.39 - 1,671.04 MWD +IFR- AK- CAZ -SC (2) 4,776.50 37.96 284.86 4,132.63 4,083.93 668.84 - 1,964.58 6,004,477.99 386,000.61 0.62 - 1,716.47 MWD +IFR- AK- CAZ -SC (2) 2/8/2010 9 :58 :51AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Site CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft ( Doyon 19) Well: CD3 - 122 North Reference: True Weilbore: CD3 - 122 Survey Calculation Method: Minimum Curvature Design: CD3 - 122 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/-W Northing Easting DLS :Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) r1100') (f() Survey Tool Name - 4,872.50 36.89 284.32 4,208.86 4,160.16 683.53 - 2,021.04 6,004,493.53 385,944.38 1.17 - 1,762.18 MWD +IFR -AK- CAZ -SC (2) 4,967.31 37.71 286.50 4,284.29 4,235.59 698.81 - 2,076.41 6,004,509.63 385,889.25 1.64 - 1,807.71 MWD +IFR -AK- CAZ -SC (2) 5,062.50 37.79 286.23 4,359.55 4,310.85 715.23 - 2,132.33 6,004,526.89 385,833.59 0.19 - 1,854.47 MWD +IFR -AK- CAZ -SC (2) 5,157.80 38.42 285.59 4,434.54 4,385.84 731.35 - 2,188.89 6,004,543.85 385,777.28 0.78 - 1,901.38 MWD +IFR -AK- CAZ -SC (2) 5,253.11 37.34 284.97 4,509.77 4,461.07 746.77 - 2,245.34 6,004,560.12 385,721.08 1.20 - 1,947.68 MWD +IFR -AK- CAZ -SC (2) 5,348.76 38.71 285.01 4,585.11 4,536.41 762.01 - 2,302.25 6,004,576.22 385,664.40 1.43 - 1,994.10 MWD +IFR -AK- CAZ -SC (2) 5,443.93 37.58 284.80 4,659.96 4,611.26 777.13 - 2,359.05 6,004,592.19 385,607.84 1.20 - 2,040.36 MWD +IFR -AK- CAZ -SC (2) 5,537.72 38.18 284.75 4,733.99 4,685.29 791.82 - 2,414.74 6,004,607.70 385,552.38 0.64 - 2,085.60 MWD +IFR -AK- CAZ -SC (2) 5,633.63 37.77 284.04 4,809.59 4,760.89 806.49 - 2,471.90 6,004,623.23 385,495.45 0.62 - 2,131.72 MWD +IFR -AK- CAZ -SC (2) 5,728.87 37.95 285.54 4,884.79 4,836.09 821.41 - 2,528.41 6,004,639.00 385,439.18 0.98 - 2,177.65 MWD +IFR -AK- CAZ -SC (2) 5,824.13 38.46 285.15 4,959.64 4,910.94 837.00 - 2,585.23 6,004,655.44 385,382.61 0.59 - 2,224.29 MWD +IFR -AK- CAZ -SC (2) 5,919.50 38.27 284.08 5,034.42 4,985.72 851.94 - 2,642.50 6,004,671.23 385,325.57 0.72 - 2,270.69 MWD +IFR -AK- CAZ -SC (2) 6,014.53 37.99 284.23 5,109.17 5,060.47 866.29 - 2,699.40 6,004,686.43 385,268.90 0.31 - 2,316.39 MWD +IFR -AK- CAZ -SC (2) 6,109.30 38.50 284.11 5,183.60 5,134.90 880.65 - 2,756.28 6,004,701.64 385,212.25 0.54 - 2,362.09 MWD +IFR -AK- CAZ -SC (2) 6,204.33 37.87 282.94 5,258.30 5,209.60 894.39 - 2,813.39 6,004,716.24 385,155.35 1.01 - 2,407.43 MWD +IFR -AK- CAZ -SC (2) 6,299.44 37.68 282.78 5,333.47 5,284.77 907.36 - 2,870.19 6,004,730.06 385,098.76 0.22 - 2,451.97 MWD +IFR -AK- CAZ -SC (2) 6,394.77 37.56 282.84 5,408.98 5,360.28 920.26 - 2,926.93 6,004,743.81 385,042.22 0.13 - 2,496.43 MWD +IFR -AK- CAZ -SC (2) 6,489.78 37.67 280.77 5,484.25 5,435.55 932.12 - 2,983.69 6,004,756.52 384,985.65 1.33 - 2,540.06 MWD +IFR -AK- CAZ -SC (2) 6,540.84 37.42 279.01 5,524.73 5,476.03 937.47 - 3,014.34 6,004,762.32 384,955.09 2.16 - 2,562.77 MWD +IFR -AK- CAZ -SC (2) 6,584.93 38.22 275.13 5,559.56 5,510.86 940.79 - 3,041.16 6,004,766.04 384,928.32 5.69 - 2,581.56 MWD+IFR -AK- CAZ -SC (2) 6,632.72 37.96 272.88 5,597.18 5,548.48 942.85 - 3,070.56 6,004,768.54 384,898.96 2.95 - 2,600.90 MWD +IFR -AK- CAZ -SC (2) 6,679.90 37.87 270.95 5,634.40 5,585.70 943.82 - 3,099.54 6,004,769.95 384,870.00 2.52 - 2,619.11 MWD +IFR -AK- CAZ -SC (2) 6,726.94 37.47 270.59 5,671.64 5,622.94 944.20 - 3,128.28 6,004,770.77 384,841.27 0.97 - 2,636.72 MWD +IFR -AK- CAZ -SC (2) 6,774.83 36.60 270.47 5,709.86 5,661.16 944.47 - 3,157.12 6,004,771.47 384,812.44 1.82 - 2,654.29 MWD +IFR -AK- CAZ -SC (2) 6,820.80 36.19 270.36 5,746.87 5,698.17 944.67 - 3,184.40 6,004,772.07 384,785.17 0.90 - 2,670.86 MWD +IFR -AK- CAZ -SC (2) 6,870.19 36.20 270.23 5,786.73 5,738.03 944.82 - 3,213.56 6,004,772.66 384,756.01 0.16 - 2,688.54 MWD +IFR -AK- CAZ -SC (2) 6,916.68 36.65 270.45 5,824.13 5,775.43 944.98 - 3,241.17 6,004,773.24 384,728.42 1.01 - 2,705.28 MWD +IFR -AK- CAZ -SC (2) 6,964.97 37.15 269.45 5,862.75 5,814.05 944.96 - 3,270.16 6,004,773.65 384,699.43 1.62 - 2,722.71 MWD +IFR -AK- CAZ -SC (2) 7,011.95 36.84 265.89 5,900.28 5,851.58 943.81 - 3,298.40 6,004,772.93 384,671.18 4.61 - 2,738.78 MWD +IFR -AK- CAZ -SC (2) 7,060.02 36.97 262.42 5,938.72 5,890.02 940.87 - 3,327.10 6,004,770.42 384,642.44 4.34 - 2,753.71 MWD +IFR -AK- CAZ -SC (2) 7,106.86 37.31 259.30 5,976.06 5,927.36 936.38 - 3,355.02 6,004,766.34 384,614.46 4.09 - 2,766.92 MWD +IFR -AK- CAZ -SC (2) 7,155.35 37.68 255.84 6,014.54 5,965.84 930.02 - 3,383.83 6,004,760.42 384,585.56 4.41 - 2,779.19 MWD +IFR -AK- CAZ -SC (2) 7,202.54 37.63 252.38 6,051.90 6,003.20 922.13 - 3,411.55 6,004,752.95 384,557.73 4.48 - 2,789.57 MWD +IFR -AK- CAZ -SC (2) 7,250.88 36.82 248.20 6,090.40 6,041.70 912.28 - 3,439.07 6,004,743.52 384,530.07 5.49 - 2,798.26 MWD +IFR -AK- CAZ -SC (2) 7,297.84 36.30 244.31 6,128.13 6,079.43 901.03 - 3,464.66 6,004,732.65 384,504.31 5.06 - 2,804.68 MWD +IFR -AK- CAZ -SC (2) 7,346.15 36.65 240.82 6,166.98 6,118.28 887.80 - 3,490.14 6,004,719.80 384,478.64 4.35 - 2,809.45 MWD +IFR -AK- CAZ -SC (2) 7,392.71 37.03 237.86 6,204.24 6,155.54 873.56 - 3,514.15 6,004,705.93 384,454.42 3.90 - 2,812.53 MWD +IFR -AK- CAZ -SC (2) 7,441.04 38.07 234.59 6,242.56 6,193.86 857.19 - 3,538.62 6,004,689.93 384,429.71 4.65 - 2,814.17 MWD +IFR -AK- CAZ -SC (2) 7,492.90 38.65 230.77 6,283.23 6,234.53 837.68 - 3,564.20 6,004,670.80 384,403.84 4.71 - 2,813.99 MWD +IFR -AK- CAZ -SC (2) 7,536.23 40.07 226.79 6,316.74 6,268.04 819.57 - 3,584.85 6,004,653.01 384,382.92 6.68 - 2,811.95 MWD +IFR -AK- CAZ -SC (2) 2/8/2010 9 :58:51AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Well: CD3 - 122 North Reference: True Wetibore; CD3 - 122 Survey Calculation Method: Minimum Curvature Design: CD3 - 122 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl -S +E / -W Northing Easting DLS Section (ft) ( (°) (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 7,582.70 41.13 222.80 6,352.03 6,303.33 798.11 - 3,606.14 6,004,631.87 384,361.32 6.03 - 2,807.62 MWD +IFR- AK- CAZ -SC (2) 7,631.83 42.12 220.13 6,388.76 6,340.06 773.65 - 3,627.74 6,004,607.75 384,339.35 4.13 - 2,801.09 MWD +IFR- AK- CAZ -SC (2) 7,679.90 42.89 217.34 6,424.20 6,375.50 748.32 - 3,648.05 6,004,582.72 384,318.66 4.24 - 2,793.09 MWD +IFR- AK- CAZ -SC (2) 7,726.51 43.84 213.80 6,458.09 6,409.39 722.29 - 3,666.65 6,004,556.98 384,299.67 5.60 - 2,783.49 MWD +IFR- AK- CAZ -SC (2) 7,775.73 44.52 211.12 6,493.39 6,444.69 693 35 - 3,685.06 6,004,528.32 384,280.84 4.04 - 2,771.46 MWD +IFR- AK- CAZ -SC (2) 7,822.14 46.06 208.25 6,526.04 6,477.34 664.70 - 3,701.38 6,004,499.92 384,264.09 5.51 - 2,758.40 MWD +IFR- AK- CAZ -SC (2) 7,869.71 47.60 204.70 6,558.59 6,509.89 633.65 - 3,716.83 6,004,469.11 384,248.18 6.33 - 2,742.89 MWD +IFR- AK- CAZ -SC (2) 7,917.23 49.30 201.31 6,590.11 6,541.41 600.92 - 3,730.71 6,004,436.59 384,233.81 6.43 - 2,725.11 MWD +IFR- AK- CAZ -SC (2) 7,964.51 50.15 199.49 6,620.68 6,571.98 567.11 - 3,743.28 6,004,402.98 384,220.74 3.44 - 2,705.67 MWD +IFR- AK- CAZ -SC (2) 8,012.49 52.02 197.23 6,650.82 6,602.12 531.68 - 3,755.02 6,004,367.73 384,208.46 5.35 - 2,684.45 MWD +IFR- AK- CAZ -SC (2) 8,057.42 53.65 195.23 6,677.96 6,629.26 497.30 - 3,765.02 6,004,333.51 384,197.95 5.07 - 2,663.01 MWD +IFR- AK- CAZ -SC (2) 8,108.28 55.08 192.94 6,707.60 6,658.90 457.21 - 3,775.07 6,004,293.58 384,187.29 4.61 - 2,637.04 MWD +IFR- AK- CAZ -SC (2) 8,155.44 57.85 191.66 6,733.65 6,684.95 418.81 - 3,783.44 6,004,255.31 384,178.35 6.29 - 2,611.41 MWD +IFR- AK- CAZ -SC (2) 8,202.86 60.12 190.14 6,758.08 6,709.38 378.91 - 3,791.12 6,004,215.53 384,170.08 5.52 - 2,584.16 MWD +IFR- AK- CAZ -SC (2) 8,246.85 62.81 188.32 6,779.09 6,730.39 340.77 - 3,797.31 6,004,177.49 384,163.32 7.11 - 2,557.42 MWD +IFR- AK- CAZ -SC (2) 8,297.95 65.27 186.33 6,801.46 6,752.76 295.20 - 3,803.16 6,004,132.02 384,156.79 5.95 - 2,524.56 MWD +IFR- AK- CAZ -SC (2) 8,344.71 66.20 184.57 6,820.68 6,771.98 252.77 - 3,807.20 6,004,089.66 384,152.10 3.97 - 2,493.10 MWD +IFR- AK- CAZ -SC (2) 8,392.73 68.08 182.90 6,839.34 6,790.64 208.62 - 3,810.08 6,004,045.56 384,148.56 5.06 - 2,459.57 MWD +IFR- AK- CAZ -SC (2) 8,440.64 69.68 181.17 6,856.60 6,807.90 163.96 - 3,811.66 6,004,000.93 384,146.31 4.74 - 2,424.86 MWD +IFR- AK- CAZ -SC (2) 8,487.82 71.46 179.96 6,872.29 6,823.59 119.47 - 3,812.10 6,003,956.46 384,145.21 4.48 - 2,389.59 MWD +IFR- AK- CAZ -SC (2) 8,535.70 73.14 177.99 6,886.85 6,838.15 73.87 - 3,811.28 6,003,910.85 384,145.34 5.26 - 2,352.68 MWD +IFR- AK- CAZ -SC (2) 8,583.38 74.99 175.65 6,899.94 6,851.24 28.10 - 3,808.73 6,003,865.05 384,147.20 6.11 - 2,314.59 MWD +IFR- AK- CAZ -SC (2) 8,630.95 76.75 173.56 6,911.56 6,862.86 -17.83 - 3,804.39 6,003,819.08 384,150.85 5.64 - 2,275.31 MWD +IFR- AK- CAZ -SC (2) 8,678.63 79.03 171.17 6,921.56 6,872.86 -64.02 - 3,798.20 6,003,772.79 384,156.35 6.85 - 2,234.68 MWD +IFR- AK- CAZ -SC (2) 8,726.54 80.97 169.23 6,929.88 6,881.18 - 110.51 - 3,790.16 6,003,726.19 384,163.69 5.68 - 2,192.72 MWD +IFR- AK- CAZ -SC (2) 8,773.84 82.86 167.96 6,936.53 6,887.83 -15641 - 3,780.90 6,003,680.16 384,172.26 4.80 - 2,150.49 MWD +IFR- AK- CAZ -SC (2) 8,821.74 85.33 166.70 6,941.46 6,892.76 - 202.90 - 3,770.45 6,003,633.53 384,182.01 5.78 - 2,107.08 MWD +IFR- AK- CAZ -SC (2) 8,868.87 87.52 165.05 6,944.40 6,895.70 - 248.51 - 3,758.97 6,003,587.76 384,192.80 5.81 - 2,063.74 MWD +IFR- AK- CAZ -SC (2) 8,916.68 87.58 165.19 6,946.44 6,897.74 - 294.67 - 3,746.71 6,003,541.42 384,204.37 0.32 - 2,019.49 MWD +IFR- AK- CAZ -SC (2) 8,96406 87.64 165.65 6,948.42 6,899.72 - 340.49 - 3,734.79 6,003,495.44 384,215.60 0.98 - 1,975.73 MWD +IFR- AK- CAZ -SC(2) 9,011.71 86.81 165.35 6,950.73 6,902.03 - 386.56 - 3,722.87 6,003,449.19 384,226.82 1.85 - 1,931.76 MWD +IFR- AK- CAZ -SC (2) 9,058.70 86.20 163.35 6,953.59 6,904.89 - 431.72 - 3,710.22 6,003,403.85 384,238.79 4A4 - 1,888.08 MWD +IFR- AK- CAZ -SC (2) 9,097.85 86.28 162.36 6,956.16 6,907.46 - 469.05 - 3,698.71 6,003,366.35 384,249.75 2.53 - 1,851.33 MWD +IFR- AK- CAZ -SC (2) 9,160.08 86.40 161.74 6,960.13 6,911.43 - 528.13 - 3,679.57 6,003,307.00 384,267.99 1.01 - 1,792.63 MWD +IFR- AK- CAZ -SC (2) 9,223.15 88.32 160.53 6,963.04 6,914.34 - 587.75 - 3,659.20 6,003,247.09 384,287.47 3.60 - 1,732.76 MWD +IFR- AK- CAZ -SC (2) 9,317.71 90.17 157.91 6,964.28 6,915.58 - 676.14 - 3,625.66 6,003,158.21 384,319.67 3.39 - 1,641.99 MWD +IFR- AK- CAZ -SC (2) 9,415.94 91.03 155.12 6,963.25 6,914.55 - 766.22 - 3,586.52 6,003,067.56 384,357.45 2.97 - 1,546.49 MWD +IFR- AK- CAZ -SC (2) 9,508.35 89.99 152.00 6,962.43 6,913.73 - 848.95 - 3,545.38 6,002,984.23 384,397.34 3.56 - 1,455.66 MWD +IFR- AK- CAZ -SC (2) 9,606.34 87.51 148.38 6,964.57 6,915.87 - 933.93 - 3,496.69 6,002,898.54 384,444.75 4.48 - 1,358.49 MWD +IFR- AK- CAZ -SC (2) 9,702.71 89.43 146.15 6,967.14 6,918.44 - 1,014.96 - 3,444.60 6,002,816.74 384,495.61 3.05 - 1,262.43 MWD +IFR- AK- CAZ -SC (2) 2/8/2010 9 :58:51AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft ( Doyon 19) Well: CD3 - 122 North Reference: True Weltbore: CD3 - 122 Survey Calculation Method: Minimum Curvature Design: CD3 - 122 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E /-W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 9,797.40 89.43 144.51 6,968.08 6,919.38 - 1,092.83 - 3,390.74 6,002,738.08 384,548.29 1.73 - 1,167.83 MWD +IFR- AK- CAZ -SC (2) 9,893.06 88.01 142.28 6,970.22 6,921.52 - 1,169.59 - 3,333.72 6,002,660.47 384,604.15 2.76 - 1,072.20 MWD +IFR- AK- CAZ -SC (2) 9,988.48 89.80 142.54 6,972.04 6,923.34 - 1,245.19 - 3,275.52 6,002,584.02 384,661.20 1.90 - 976.81 MW D+ I FR-AK-CAZ-SC (2) 10,080.16 89.24 145.14 6,972.81 6,924.11 - 1,319.20 - 3,221.44 6,002,509.21 384,714.16 2.90 - 885.15 MWD +IFR- AK- CAZ -SC (2) 10,179.56 89.00 139.75 6,974.34 6,925.64 - 1,397.96 - 3,160.88 6,002,429.56 384,773.53 5.43 - 785.80 MWD +IFR- AK- CAZ -SC (2) 10,228.17 87.95 138.24 6,975.63 6,926.93 - 1,434.63 - 3,129.00 6,002,392.42 384,804.85 3.78 - 737.33 MWD +IFR- AK- CAZ -SC (2) 10,275.02 89.37 138.62 6,976.73 6,928.03 - 1,469.67 - 3,097.92 6,002,356.92 384,835.40 3.14 - 690.65 MWD +IFR- AK- CAZ -SC (2) 10,370.77 86.65 137.43 6,980.05 6,931.35 - 1,540.80 - 3,033.93 6,002,284.84 384,898.31 3.10 - 595.32 MWD +IFR- AK- CAZ -SC (2) 10,466.15 86.71 138.26 6,985.58 6,936.88 - 1,611.39 - 2,970.02 6,002,213.30 384,961.14 0.87 - 500.49 MWD+ I FR-AK-CAZ-SC (2) 10,561.73 89.43 139.42 6,988.80 6,940.10 - 1,683.30 - 2,907.16 6,002,140.46 385,022.91 3.09 - 405.23 MWD +IFR- AK- CAZ -SC (2) 10,657.26 89.86 139.36 6,989.39 6,940.69 - 1,755.82 - 2,844.98 6,002,067.02 385,083.99 0.45 - 309.89 MWD +IFR- AK- CAZ -SC (2) 10,752.61 90.29 138.57 6,989.26 6,940.56 - 1,827.75 - 2,782.38 6,001,994.18 385,145.50 0.94 - 214.78 MWD+ I FR-AK-CAZ-SC (2) 10,848.28 89.92 139.74 6,989.09 6,940.39 - 1,900.12 - 2,719.81 6,001,920.88 385,206.97 1.28 - 119.32 MWD +IFR- AK- CAZ -SC (2) 10,943.76 90.11 139.72 6,989.06 6,940.36 - 1,97297 - 2,658.10 6,001,847.12 385,267.58 0.20 -24.00 MWD +IFR- AK- CAZ -SC(2) 11,035.61 89.86 139.88 6,989.09 6,940.39 - 2,043.12 - 2,598.81 6,001,776.09 385,325.80 0.32 67.71 MWD +IFR- AK- CAZ -SC (2) 11,134.92 89.37 139.35 6,989.76 6,941.06 - 2,118.77 - 2,534.47 6,001,699.49 385,388.99 0.73 166.84 MW D+ I FR-AK-CAZ-SC (2) 11,227.79 90.42 139.76 6,989.93 6,941.23 - 2,189.44 - 2,474.22 6,001,627.93 385,448.17 1.21 259.54 MWD+ I FR-AK-CAZ-SC (2) 11,325.97 90.85 140.57 6,988.84 6,940.14 - 2,264.83 - 2,411.33 6,001,551.61 385,509.91 0.93 357.60 MW D+ I FR-AK-CAZ-SC (2) 11,420.23 90.05 140.06 6,988.10 6,939.40 - 2,337.37 - 2,351.15 6,001,478.19 385,569.00 1.01 451.75 MW D+ I FR-AK-CAZ-SC (2) 11,517.40 90.23 140.71 6,987.86 6,939.16 - 2,412.22 - 2,289.19 6,001,402.42 385,629.82 0.69 548.82 MWD +IFR- AK- CAZ -SC (2) 11,612.87 90.05 142.26 6,987.63 6,938.93 - 2,486.92 - 2,229.74 6,001,326.84 385,688.14 1.63 644.25 MW D+ I FR-AK-CAZ-SC (2) 11,708.79 88.69 141.75 6,988.68 6,939.98 - 2,562.50 - 2,170.70 6,001,250.39 385,746.03 1.51 740.15 MW D+ I FR-AK-CAZ-SC (2) 11,803.82 89.86 141.45 6,989.88 6,941.18 - 2,636.97 - 2,111.68 6,001,175.05 385,803.93 1.27 835.14 MW D+ I FR-AK-CAZ-SC (2) 11,899.81 89.99 142.08 6,990.01 6,941.31 - 2,712.37 - 2,052.27 6,001,098.77 385,862.19 0.67 931.11 MWD+ I FR-AK-CAZ-SC (2) 11,991.18 90.97 142.42 6,989.24 6,940.54 - 2,784.61 - 1,996.33 6,001,025.71 385,917.03 1.14 1,022.46 MWD +IFR- AK- CAZ -SC (2) 12,090.49 89.68 143.80 6,988.68 6,939.98 - 2,864.03 - 1,936.72 6,000,945.41 385,975.44 1.90 1,121.77 MWD +IFR- AK- CAZ -SC (2) 12,181.30 89.61 141.79 6,989.24 6,940.54 - 2,936.35 - 1,881.82 6,000,872.27 386,029.25 2.21 1,212.57 MWD +IFR- AK- CAZ -SC (2) 12,282.42 89.06 139.90 6,990.42 6,941.72 - 3,014.76 - 1,817.98 6,000,792.93 386,091.90 1.95 1,313.61 MWD +IFR- AK- CAZ -SC (2) 12,376.03 88.32 139.39 6,992.56 6,943.86 - 3,086.07 - 1,757.38 6,000,720.72 386,151.41 0.96 1,407.03 MWD +IFR- AK- CAZ -SC (2) 12,473.60 89.43 140.82 6,994.47 6,945.77 - 3,160.91 - 1,694.81 6,000,644.95 386,212.84 1.86 1,504.45 MW D+ I FR-AK-CAZ-SC (2) 12,567.12 89.18 141.22 6,995.61 6,946.91 - 3,233.61 - 1,635.99 6,000,571.39 386,270.56 0.50 1,597.91 MWD +IFR- AK- CAZ -SC (2) 12,665.00 89.99 141.30 6,996.32 6,947.62 - 3,309.95 - 1,574.74 6,000,494.14 386,330.66 0.83 1,695.74 MWD +IFR- AK- CAZ -SC (2) 12,760.71 89.06 140.15 6,997.11 6,948.41 - 3,384.04 - 1,514.15 6,000,419.16 386,390.12 1.55 1,791.37 MWD +IFR- AK- CAZ -SC (2) 12,856.36 89.24 141.83 6,998.53 6,949.83 - 3,458.35 - 1,453.95 6,000,343.96 386,449.19 1.77 1,886.95 MWD +IFR- AK- CAZ -SC (2) 12,951.11 90.11 143.80 6,999.07 6,950.37 - 3,533.83 - 1,396.69 6,000,267.63 386,505.31 2.27 1,981.69 MWD +IFR- AK- CAZ -SC (2) 13,047.18 90.54 144.50 6,998.52 6,949.82 - 3,611.70 - 1,340.43 6,000,188.94 386,560.39 0.86 2,077.74 MWD +IFR- AK- CAZ -SC (2) 13,143.36 89.37 145.46 6,998.60 6,949.90 - 3,690.46 - 1,285.24 6,000,109.36 386,614.39 1.57 2,173.86 MWD +IFR- AK- CAZ -SC(2) 13,235.21 88.26 145.59 7,000.50 6,951.80 - 3,766.16 - 1,233.26 6,000,032.89 386,665.22 1.22 2,265.60 MW D+ I FR-AK-CAZ-SC (2) 13,334.90 88.01 144.06 7,003.74 6,955.04 - 3,847.60 - 1,175.86 5,999,950.61 386,721.39 1.55 2,365.18 MW D+ I FR-AK-CAZ-SC (2) 13,430.54 88.13 142.44 7,006.96 6,958.26 - 3,924.19 - 1,118.67 5,999,873.18 386,777.41 1.70 2,460.76 MWD +IFR- AK- CAZ -SC (2) 218/2010 9 :58 :51AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD3 -122 Project: Western North Slope TVD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -122 (36.1 +12.6) @ 48.70ft (Doyon 19) Well: CD3 -122 North Reference: True Wellbore: CD3 -122 Survey Calculation Method: Minimum Curvature Design: CD3 -122 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD NOSS +N / -S +El -W Northing Easting DLS Section (ft) ( °) ( ) (ft) • (ft) (ft) (ft) (ft) (ft) ( °!100') (ft) Survey Tool Name 13,526.34 88.26 141.57 7,009.98 6,961.28 - 3,999.65 - 1,059.73 5,999,796.85 386,835.21 0.92 2,556.50 MWD +IFR- AK- CAZ -SC (2) 13,622.09 87.82 141.71 7,013.25 6,964.55 -4,074.68 - 1,000.34 5,999,720.94 386,893.46 0.48 2,652.17 MWD +IFR- AK- CAZ -SC (2) 13,717.83 88.44 141.65 7,016.38 6,967.68 - 4,149.76 - 941.01 5,999,644.99 386,951.66 0.65 2,747.83 MWD +IFR- AK- CAZ -SC (2) 13,813.18 89.06 142.21 7,018.46 6,969.76 - 4,224.80 - 882.23 5,999,569.08 387,009.30 0.88 2,843.14 MWD +IFR- AK- CAZ -SC (2) 13,909.33 89.18 141.07 7,019.94 6,971.24 - 4,300.19 - 822.56 5,999,492.81 387,067.82 1.19 2,939.25 MWD +IFR- AK- CAZ -SC (2) 14,004.99 89.00 140.58 7,021.45 6,972.75 - 4,374.34 - 762.14 5.999,417.77 387,127.11 0.55 3,034.83 MWD +IFR- AK- CAZ -SC (2) 14,100.63 87.58 142.05 7,024.31 6,975.61 - 4,448.95 - 702.40 5,999,342.27 387,185.73 2.14 3,130.38 MWD +IFR- AK- CAZ -SC (2) 14,196.43 88.01 143.32 7,027.99 6,979.29 - 4,525.09 - 644.37 5.999,265.28 387,242.61 1.40 3,226.11 MWD +IFR- AK- CAZ -SC (2) 14,292.06 88.69 143.36 7,030.75 6,982.05 - 4,601.77 - 587.29 5,999,187.76 387,298.52 0.71 3,321.69 MWD +IFR- AK- CAZ -SC (2) 14,387.74 87.87 141.96 7,033.62 6,984.92 - 4,677.80 - 529.29 5,999,110.87 387,355.37 1.70 3,417.33 MWD +IFR- AK- CAZ -SC (2) 14,483.45 88.63 142.75 7,036.54 6,987.84 - 4,753.55 - 470.86 5,999,034.26 387,412.65 1.15 3,512.98 MWD +IFR- AK- CAZ -SC (2) 14,579.18 89.68 142.83 7,037.95 6,989.25 - 4,829.78 - 412.97 5,998,957.18 387,469.38 1.10 3,608.70 MW D+ I FR-AK-CAZ-SC (2) 14,674.93 88.75 142.42 7,039.27 6,990.57 -4,905.86 - 354.86 5,998,880.24 387,526.34 1.06 3,704.44 MWD +IFR- AK- CAZ -SC (2) 14,763.38 88.87 142.37 7,041.10 6,992.40 - 4,975.92 - 300.90 5,998,809.38 387,579.24 0.15 3,792.86 MWD +IFR- AK- CAZ -SC (2) 14,866.04 88.94 142.20 7,043.07 6,994.37 - 5,057.12 - 238.11 5,998,727.26 387,640.80 0.18 3,895.50 MWD +IFR- AK- CAZ -SC (2) 14,958.06 88.07 141.77 7,045.47 6,996.77 - 5,129.59 - 181.45 5,998,653.95 387,696.35 1.05 3,987.47 MWD +IFR- AK- CAZ -SC (2) 15,057.25 90.54 142.53 7,046.67 6,997.97 - 5,207.90 - 120.60 5,998,574.74 387,756.02 2.61 4,086.63 MWD +IFR- AK- CAZ -SC (2) 15,150.73 93.01 143.28 7,043.77 6,995.07 - 5,282.42 -64.25 5,998,499.39 387,811.24 2.76 4,180.06 MWD +IFR- AK- CAZ -SC (2) 15,246.96 93.82 142.72 7,038.04 6,989.34 - 5,359.14 -6.44 5,998,421.82 387,867.89 1.02 4,276.12 MWD+ I FR-AK-CAZ-SC (2) 15,342.39 93.08 141.46 7,032.30 6,983.60 - 5,434.29 52.08 5,998,345.81 387,925.27 1.53 4,371.36 MWD +IFR- AK- CAZ -SC (2) . 15,408.00 93.08 141.46 7,028.77. 6,980.07 - 5,485.53 92.90 5,998,293.96 387,965.32 0.00 4,436.85 PROJECTED to TD 21812010 9 :58 :51AM Page 7 COMPASS 2003.16 Build 69 • ConocoPhillips Time Log & Summary We/Iwew Web Reporting Report Well Name: CD3 - 122 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 1/12/2010 5:00:00 AM Rig Release: 2/5/2010 11:00:00 PM Time,Logs Date From To - - Dur- S. Depth E. Depth Phase Code Subcode T Comment 01/10/2010 24 hr Summary Prepare/Move Rig f/ CD4 -24 to CD3 -122 13:00 00:00 11.00 0 0 MIRU MOVE MOB P Move Rig From CD4 -24 to CD3 -122 01/11/2010 Continue to Mobilize the Rig f/ CD4 to CD3 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue to Mobilize the Rig & Ball Mill f /CD4 to CD3 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Continue to Mobilize the Rig and Ball Mill f /CD4 to CD3 01/12/2010 Continue to spot and level rig over hole, PJSM, skid rig floor, Spot motor and pit module, RU service lines, RU hi line- on highline at 0500 hrs 1/12/2010, Accept rig at 0500 hrs 1/12/2010. PJSM, NU riser, clean floor, PJSM, slip and cut 60' of 1 -3/8" drilling line. MU drilling assembly to clean out conductor, lay down assembly, PU/MU 25 stands of 5" DP and 8 stands of 5" HWDP. Service rig, PU /MU BHA #1, pre spud meeting, fill stack check f/ leaks, test mud line to 3500 psi, rig up Sperry Sun e line f/ gyro's, test methane and H2S gas alarms, spud at 2330 hrs 1/12/2010, drilling f/ 114' to 168' at midnight. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Continue to spot , level and shim sub base over the hole. Remove clamps for the rig floor. 01:00 01:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on skidding rig floor. 01:15 03:00 1.75 0 0 MIRU MOVE MOB P Move motor module and pit module. Spot, level and shim pits and motors. 03:00 05:00 2.00 0 0 MIRU MOVE RURD P Rig up service lines (steam, air, water, mud. Pull hi line trailer into position, pull hi line cable, hook up hi line. Swap to hi line at 0500 hrs 1/12/2010. Rig accepted at 0500 hrs 1/12/2010. 05:00 05:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on nippling up surface riser. 05:15 08:30 3.25 0 0 MIRU WHDBO NUND P Nipple up riser, hook up and thaw out lines. 08:30 09:00 0.50 0 0 MIRU MOVE RURD P Pick up and install mouse hole. 09:00 10:00 1.00 0 0 MIRU MOVE PULD P Lay down equipment from floor. Pick up bit and bit sub. Clean and clear rig floor. 10:00 10:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on cutting drilling line. 10:15 12:00 1.75 0 0 MIRU RIGMNT SLPC P Slip and cut 60' of 1 -3/8" drilling line. Service the top drive. 12:00 13:30 1.50 0 0 MIRU MOVE PULD P Make up drilling assembly to clean out conductor to 114'. Lay down drilling assembly. No ice in the conductor. Page 1 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 18:00 4.50 0 0 MIRU MOVE PULD P Pick up and stand back in the derrick 25 stands of 5" drill pipe. Pick up 8 stands of 5" HWDP. 18:00 18:30 0.50 0 0 MIRU RIGMNT SVRG P Service rig. 18:30 20:30 2.00 0 0 MIRU MOVE PULD P Pick up BHA #1. 20:30 21:00 0.50 0 0 MIRU MOVE SFTY P Pre spud meeting. 21:00 22:30 1.50 0 0 MIRU MOVE PRTS P Fill stack w/ mud, check for leaks. Test mud line to 3500 psi. Hang sheave and rig up Sperry Sun a -line for gyro surveys. 22:30 23:30 1.00 0 0 MIRU MOVE OTHR P Test methane and H2S gas alarms. 23:30 00:00 0.50 0 168 SURFA( DRILL DDRL P Spud: Drill f/ 114' to 168'. Drill w/ 5k weight on bit. Rotate 40 rpm w/ 4k ft Ibs of torque. Pumping 448 gpm w/ 620 psi. Actual driling time .43 hrs. 01/13/2010 continue drillina 12 -1/4" surface from 168' to 1570' w/ GyroData surveys. Multishot surveys every 50' to surface. Continue to drill 12 -1/4" surface hole f/ 1570' to 2122'. 00:00 12:00 12.00 168 821 SURFA( DRILL DDRL P Drill f/ 168' to 874', w/ Gyro Data surveys. Drill w/ 5 -25k weight on bit. Rotate 40 to 60 rpm w/ 4 to 6k ft Ibs of torque on bottom, 4 to 4.5k off bottom . Pumping 448 gpm w/ 620 to 950 psi. Actual driling time 6.09 hrs, 3.53 rotating and 2.56 hrs sliding. 12:00 17:30 5.50 821 1,570 SURFA( DRILL DDRL P Drill f/ 874' to 1570', w/ Gyro Data surveys. Drill w/ 10 to 25k weight on bit. Rotate 60 to 80 rpm w/ 6 to 6.5k ft Ibs of torque on bottom, 4.5 to 5.5k off bottom . Pumping 448 to 550 gpm w/ 950 to 1340 psi. Actual driling time 4.53 hrs, 2.26 rotating and 2.27 hrs sliding. PU wt 130k, SO wt 128k, Rot wt 128k. 17:30 19:30 2.00 1,570 1,570 SURFA( DRILL SRVY P Gyro survey, then multishot survey to surface every 50'. 19:30 00:00 4.50 1,570 2,122 SURFA( DRILL DDRL P Drill 12 -1/4" surface hole f/ 1570' to 2122'. Drill w/ 10 to 25k weight on bit. Rotate 80 rpm w/ 6.5 to 7k ft Ibs of torque on bottom, 4.5 to 5k off bottom . Pumping 550 to 600 gpm w/ 1340 to 1300 psi. Actual driling time 2.78 hrs, .62 rotating and 2.78 hrs sliding. PU wt 133k, SO wt 133k, Rot wt 135k. 01/14/2010 Continue to drill 12 -1/4" surface hole f/ 2122' to 2695' (2492' TVD). Circulate and condition mud and hole, Backream out from 2695' to 908', blow down the top drive, monitor well- static, trip in f/ 908' to 2695', circulate bottom's up, Trip out to 169', lay down BHA #1. Clear floor. Rig up to run 9 -5/8" surface casing. Pre job safety meeting. Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. Page 2 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:45 7.75 2,122 2,695 SURFA( DRILL DDRL P Drill 12 -1/4" surface hole f/ 2120' to 269 Drill w/ 10 to 25k weight on bit. Rotate 80 rpm w/ 7k ft Ibs of torque on bottom, 6k off bottom . Pumping 603 gpm w/ 1310 -1750 psi. Actual driling time 6.28 hrs, 5.02 rotating and 1.26 hrs sliding. PU wt 140k, SO wt 140k, Rot wt 141k. 07:45 09:00 1.25 2,695 2,695 SURFA( DRILL CIRC P Circulate and condition mud and hole. Pumping 650 gpm w/ 1850 psi. Rotate 80 rpm w/ 6500 ft Ibs of torque. Flow check- static. 09:00 12:45 3.75 2,695 908 SURFA( DRILL REAM P Backream out of the hole from 2695' to 908' (top of HWDP). While backreaming from 2695' to 1500': Pumping 600 gpm w/ 1550 psi. Rotate 80 rpm w/ 6500 ft Ibs of torque. While backreaming from 1500' to 908': Pumping 500 gpm w/ 1140 to 1100 psi. Rotate 80 rpm w/ 5000 ft Ibs of torque. 12:45 13:00 0.25 908 908 SURFA( DRILL OTHR P Blow down the top drive. 13:00 13:15 0.25 908 908 SURFA( DRILL OWFF P Flow check- static. Note: Went off hi- line at 1252 hrs, then back on highline at 1357 hrs 1/14/2010. Working to rearrange transformer f/ continued simops on CD3 pad. 13:15 14:15 1.00 908 2,695 SURFA( DRILL TRIP P Trip in the hole on elevators from 908' to 2695'. Hole in good condition. 14:15 15:30 1.25 2,695 2,695 SURFA( DRILL CIRC P Circulate bottom's up or hole clean. Pumping 691 to 666 gpm w/ 1700 to 1900 psi. Rotate 80 rpm w/ 6500 ft Ibs of torque. 15:30 17:30 2.00 2,695 908 SURFA( DRILL TRIP P Pull out of the hole on elevators from 2695' to 908' (top of 5" HWDP). 17:30 18:00 0.50 908 169 SURFA( DRILL TRIP P Stand back 5" HWDP f/ 908 to 169'. 18:00 19:30 1.50 169 0 SURFA( DRILL PULD P Lay down BHA #1. 19:30 20:15 0.75 0 0 SURFA( DRILL PULD P Clean and clear rig floor. 20:15 21:45 1.50 0 0 SURFA( CASING RURD P Rig up to run 9 -5/8" 40 ppf L -80 t BTC -m surface casing. 21:45 22:15 0.50 0 0 SURFA( CASING SFTY P Pre job safety meeting on running casing. 22:15 23:00 0.75 0 121 SURFA( CASING RNCS P Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Page 3 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:45 0.75 121 121 SURFA( CASING CIRC T Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. 23:45 00:00 0.25 121 121 SURFA( CASING CIRC P Fill three joints of casing, circulate surface to surface. Float equipment works fine. 01/15/2010 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to 1620' circulate bottom's up, continue to run casing to land on hanger w/ shoe @ 2685'. PJSM, rig down casing equipment, rig up Dowell cement head and lines, circulate and condition mud and hole f/ cement, Dowell cement 9 -5/8" casing, rig displace w/ 9.9 ppg mud, bump plug w/ 58 bbls of good 10.7 ppg cement to surface. Rig down cementing and casing running tools. Lay down landing joint. PJSM, nipple down, nipple up wellhead, test metal to metal seal to 1000 psi f/ 10 minutes, PJSM, nipple up BOPE, rig up to test, test BOPE w/ 5" test joint. Witness of test waived by AOGCC inspector Jeff Jones. Pull test joint and test plug, install FMC wear bushing, rig up drilling bales and 5" drill pipe elevators, PJSM, pick up, make up/ stand back 5" drill pipe in the derrick. 00:00 02:45 2.75 121 1,620 SURFA( CASING RNCS P Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to joint # 42 (1620'). Note: Ran centralizers one per joint up to jt # 13, then every other joint. 02:45 03:15 0.50 1,620 1,620 SURFA( CASING CIRC P Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. 03:15 04:45 1.50 1,620 2,685 SURFA( CASING RNCS P Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Continue to install bow spring centralizers over collars to joint # 67. 04:45 05:00 0.25 2,685 2,685 SURFA( CASING SFTY P Pre job safety meeting on rigging down casing tools and rigging up to cement. 05:00 05:15 0.25 2,685 2,685 SURFA( CASING RURD P Rig down casing running equip (Frank's fillup tool) 05:15 05:30 0.25 2,685 2,685 SURFA( CEMEN" RURD P Rig up u Dowell cementing head, make up 2" cementing line. 05:30 07:15 1.75 2,685 2,685 SURFA( CEMEN' CIRC P Circulate and condition mud and hole f/ cement. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. FCP= 310 psi PUW 163K SOW 149K 640 bbls pumped 07:15 07:45 0.50 2,685 2,685 SURFA( CEMEN" SFTY P Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. Page 4 of 29 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:45 2.00 2,685 2,685 SURFA( CEMEN" PUCM P Cemented 9 5/8" casing as follows: Rio pumped 80 bbls of 9.9 ppq mud, with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppq tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. 09:45 10:15 0.50 2,685 2,685 SURFA( CEMEN" DISP P Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout iob w/ 58 bbls of, 10.7 ppq cement returns to surface Reciprocated pipe until last 47 bbls of displacement. 10:15 10:30 0.25 2,685 2,685 SURFA( CEMEN" SFTY P Pre job safety meeting on rigging down cement equipment. 10:30 11:15 0.75 2,685 2,685 SURFA( CEMEN" RURD P Rig down cementing equipment. 11:15 11:30 0.25 2,685 0 SURFA( DRILL PULD P Back out FMC landing joint w/ 10.75 4SAM2 -Left hand threads. Lay down the landing joint. 11:30 11:45 0.25 0 0 SURFA( DRILL PULD P Lay down the mouse hole. Clean and clear rig floor of tools. 11:45 12:00 0.25 0 0 SURFA( WHDBO SFTY P Pre job safety meeting on nippling down surface riser. 12:00 13:15 1.25 0 0 SURFA( WHDBO NUND P Nipple down surface riser. 13:15 14:00 0.75 0 0 SURFA( WHDBO NUND P Remove FMC starting head. Install FMC wellhead. 14:00 14:15 0.25 0 0 SURFA( WHDBO DHEQ P Install FMC wellhead. Test FMC metal to metal seal to 1000 psi, hold for 10 minutes. Good test. 14:15 14:30 0.25 0 0 SURFA( WHDBO SFTY P Pre job safety meeting on nippling up BOP equipment. 14:30 16:45 2.25 0 0 SURFA( WHDBO NUND P Nipple up 13 -5/8" 5m BOP stack. 16:45 17:00 0.25 0 0 SURFA( WHDBO SFTY P Pre job safety meeting on testing BOPE. 17:00 18:00 1.00 0 0 SURFA( WHDBO BOPE P Rig up to test BOPE. Set FMC lower test plug. Fill stack and choke manifold with water. Page 5 of 29 e Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:30 3.50 0 0 SURFA( WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1550 psi after operating. Recovery time test of 33 seconds for 200 psi build up and 2 minutes 55 seconds for full charge. Nitrogen bottles average 1650 psi. 21:30 21:45 0.25 0 0 SURFA( WHDBOOTHR P Pull test joint and test plug, blow down kill and choke lines. 21:45 22:00 0.25 0 0 SURFA( WHDBOOTHR P Install FMC long wear bushing. 22:00 22:15 0.25 0 0 SURFA( DRILL RURD P Pickup short drilling bales, attach to the top drive. Install 5" drill pipe elevators. 22:15 22:30 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on picking up and standing back 5" drilllpipe. 22:30 00:00 1.50 0 0 SURFA( DRILL PULD P Pickup/ makeup/ standback in the derrick 5" drill pipe. 8 stands picked up. 01/16/2010 Continue to pick up, make up/ stand back 5" drill pipe in the derrick, PJSM, PU /MU BHA #2, upload MWD, PU 3 NM DC's, pulse test MWD, PU Weatherford jars, run 5" HWDP to 733', PU /MU RIH w 54 jts of 5" DP f/ pipe shed to 2441', circulate, PJSM, RU to test 9 -5/8" casing, test casing to 3630 psi, R/D testing equip. Trip in, tag cement @ 2564', drill cement to 2602', drill wiper plugs to top of Halliburton Sure Seal II float collar @ 2604', drill cement to Ray Oil Tool Silver bullet eccentric shoe: top @ 2682.85' and bottom @ 2685' (2484' TVD), clean out rat hole to 2695', then drill 20' of new hole to 1715'. Circulate, set back a stand, blow down the top drive. PJSM, perform pressure integrity test using 9.6 ppg mud. Apply 1100 psi. Test form picked 18.1 ppg EMW. Rig down testing equipment, make a connection and continue to drill 8 -3/4" intermediate hole from 2715' to 3868'. 00:00 03:00 3.00 0 0 SURFA( DRILL PULD P Continue to Pickup/ makeup/ standback in the derrick 38 stands more 5" drill pipe. 46 stands total stood back, 71 stands in the derrick. 03:00 03:15 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on PU /MU BHA #2. 03:15 04:30 1.25 0 84 SURFA( DRILL PULD P Pick up and make up BHA #2. Hughes 8 -3/4" HCM605Z bit, Sperry Drill motor (1.5 deg bend)nm float sub, intergral blade stabilizer, 6 -3/4" DM HOC, GR/RES /PWD /HCIM, TM HOC. 04:30 05:00 0.50 84 84 SURFA( DRILL PULD P Upload MWD. Page 6 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:30 0.50 84 268 SURFA( DRILL PULD P PU/MU three 6 -5/8" NM Flex collars, then run a stand of 5" HWDP f/ the derrick. 05:30 06:00 0.50 268 268 SURFA( DRILL DHEQ P Pulse test MWD tools. Pumping 550 gpm w/ 1200 psi. Blow down the top drive. PU wt 90k, SO wt 88k. 06:00 06:30 0.50 268 733 SURFA( DRILL PULD P PU Weatherford jars, run in the hole w/ 5" HWDP to 733'. PU wt 110k, SO wt 107k. 06:30 08:00 1.50 733 2,441 SURFA( DRILL PULD P PU /RIH w/ 5" drill pipe f/ the pipe shed to 2441'. PU wt 140k, SO wt 120k. 08:00 08:30 0.50 2,441 2,441 SURFA( DRILL CIRC P Circulate, pumping 550 gpm w/ 1720 psi. Rotate 50 rpm w/ 8k ft Ibs of torque. PU wt 140k, SO wt 120k, Rot wt 132k. Blow down the top drive. 08:30 08:45 0.25 2,441 2,441 SURFA( DRILL SFTY P Pre job safety meeting on rigging up to test casing. 08:45 09:00 0.25 2,441 2,441 SURFA( DRILL PRTS P Blow down the top drive. Rig up to test the casing. 09:00 09:45 0.75 2,441 2,441 SURFA( DRILL PRTS P Test the 9 -5/8" 40 ppf L -80 BTC -m casing to 3630 psi, lost 30 psi in 30 minutes. Good test. Blow down lines. 09:45 10:00 0.25 2,441 2,564 SURFA( DRILL TRIP P Trip in the hole from the derrick f/ 2441' to 2564' (top of cement) 10:00 10:15 0.25 2,564 2,604 SURFA( CEMEN" DRLG P Drill cement f/ 2564' to 2602', drill top and bottom wiper rubbers on top of the Halliburton sure seal II float collar @ 2603.81'. 10:15 12:00 1.75 2,604 2,695 SURFA( CEMEN" COCF P Drill cement in shoe track to Ray Oil Tools Silver Bullet eccentric shoe top @ 2682.85' and bottom at 2685'. Drill 12 -1/4" rat hole f/ 2685' to 2695' with 8 -3/4" bit.. 12:00 12:15 0.25 2,695 2,715 SURFA( DRILL DDRL P Drill 20' of new formation f/ 2695' to 2715' (2516' TVD) w/ 8 -3/4" bit. Actual drilling time .18 hrs. 12:15 12:30 0.25 2,715 2,715 SURFA( DRILL CIRC P Circulate prior to pressure integrity test. Pumping 650 gpm w/ 2090 psi. Rotate 60 rpm w/ 7.5k ft Ibs of torque. 12:30 12:45 0.25 2,715 2,631 SURFA( DRILL SFTY P Set back a stand, blow down the top drive. Pre job safety meeting on performing pressure integrity test. 12:45 13:00 0.25 2,631 2,715 SURFA( CEMEN" PRTS P Perform pressure integrity test. Mud wt 9.6 ppg, casing shoe @ 2484' TVD (2685' MD), applied 1100 psi. Test form picked EMW= 16.3 ppm Rig down testing equipment. Blow down lines. 13:00 18:00 5.00 2,715 3,297 INTRM1 DRILL DDRL P Make a connection. Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 2715' to 3297'. Drill w/ 5k weight on bit. Pumping 550 gpm w/ 1690 psi. Rotate 60 rpm w/ 8k torque on bottom and 8k torque off bottom. Page 7 of 29 'L Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,297 3,868 INTRM1 DRILL DDRL P Make a connection. Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 3297 to 3868' (3417' TVD). Drill w/ 6 to 12k weight on bit. Pumping 650 gpm w/ 1920 to 2020 psi. Rotate 80 rpm w/ 8k torque on bottom and 6.5 to 7k torque off bottom. 01/17/2010 Continue to drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 3868' to 6076' (5157' TVD). Note: Pumping bit balling sweeps every 3rd stand, two dilutions of 275 bbls each at 4200' and 5200'. 00:00 12:00 12.00 3,868 4,939 INTRMI DRILL DDRL P Make a connection. Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 3868' to 4939' (4262' TVD). Drill w/ 7 to 17k weight on bit. Pumping 650 gpm w/ 2020 to 2320 psi. Rotate 75 rpm w/ 8 to 9.5k torque on bottom and 7 to 8k torque off bottom. Actual drilling time 6.92 hrs of which 1.21 hrs was sliding. PU wt 176k, SO wt 157k, Rot wt 170k. Note: Pumped bit balling sweeps every 3rd stand. Performed 275 bbl whole mud dilutions @ 4200'. 12:00 00:00 12.00 4,939 6,076 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 4939' to 6076' (5157' TVD). Drill w/ 12 to 17k weight on bit. Pumping 650 gpm w/ 2320 to 2490 psi. Rotate 70 rpm w/ 9.5 to 11.5k torque on bottom and 8 to 10k torque off bottom. Actual drilling time 7.56 hrs of which 2.5 hrs was sliding. PU wt 195k, SO wt 175k, Rot wt 190k. Note: Pumped bit balling sweeps every 3rd stand. Performed 275 bbl whole mud dilutions @ 5200'. 01/18/2010 Continue to drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 6076' to 7578' (6349' TVD). Note: Pumping bit balling sweeps every 3rd stand, two dilutions of 275 bbls each at 6250' and 7064'. Pump a high vis sweep, circulate two bottom's up, pumping 650 gpm w/ 2040 psi, rotate 60 rpm w/ 8.5k ft Ibs of torque. 00:00 12:00 12.00 6,076 7,007 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 6076' to 7007' (5896' TVD). Drill w/ 8 to 18k weight on bit. Pumping 650 gpm w/ 2390 to 2500 psi. Rotate 70 rpm w/ 11.5 to 9.5k torque on bottom and 10 to 8k torque off bottom. Actual drilling time 7.02 hrs of which 3.15 hrs was sliding. PU wt 205k, SO wt 187k, Rot wt 197k. Note: Pumped bit balling sweeps every 3rd stand. Performed 275 bbl whole mud dilutions @ 6250'. Page 8 of 29 410 411 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22:00 10.00 7,007 7,578 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Drill motor (1.5 deg bend) from 7007' to 7578' (6349' TVD). Drill w/ 8 to 12k weight on bit. Pumping 650 gpm w/ 2460 to 2300 psi. Rotate 70 rpm w/ 10 to 10.5k torque on bottom and 8 to 9k torque off bottom. Actual drilling time 6.81 hrs of which 5.48 hrs was sliding. PU wt 220k, SO wt 195k, Rot wt 213k. Note: Pumped bit balling sweeps every 3rd stand. Performed 275 bbl whole mud dilutions @ 7064'. 22:00 00:00 2.00 7,578 7,578 INTRMI DRILL CIRC P Pump a hi vis sweep while circulating hole clean. Pumping 650 gpm w/ 2100 psi. Rotate 60 rpm w/ 9k ft Ibs of torque. 01/19/2010 Backream f/ 7578' to 2916'. Pumping 600 gpm w/ 1770 psi initial, 1500 psi final. Rotate 60 rpm w/ 8k ft Ibs initial torque and 6k ft Ibs final torque. Pulling speed 25 to 30' /minute. Circulate and condtion mud while backream f/ 2916' to 2613'. Pumping 600 gpm w/ 1500 psi. Rotate 60 rpm w/ 6k ft Ibs torque. Orient motor to high side. Blow down the top drive. Monitor well for flow- static. Service rig, top drive and iron roughneck. Visual check of drilling line- looks good. Trip in the hole from 2613' to 7483'. Make a top drive connection. Wash and ream to bottom whle circulating a bottom's up from 7483' to 7578'. Drill 8 -3/4" hole w/ SperryDrill motor (1.5 deg bend) from 7578' to 8011' (6650' TVD). Drill w/ 8 to 14k weight on bit. Pumping 625 gpm w/ 2480 to 2390 psi. Rotate 70 rpm w/ 11k torque on bottom and 9k torque off bottom. Actual drilling time 5.88 hrs of which 4.79 hrs was sliding. PU wt 228k, SO wt 197k, Rot wt 215k. Note: Performed 275 bbl inhibycol dilution while drilling @ 7578'. Additional inhibicol adding while drilling @ 4 bph. 00:00 08:15 8.25 7,578 2,916 INTRMI DRILL REAM P Backream f/ 7578' to 2916'. Pumping 600 gpm w/ 1770 psi initial, 1500 psi final. Rotate 60 rpm w/ 8k ft Ibs initial torque and 6k ft Ibs final torque. Pulling speed 25 to 30' /minute. 08:15 09:15 1.00 2,916 2,916 INTRM1 DRILL CIRC P Circulate and condtion mud while backream f/ 2916' to 2613'. Pumping 600 gpm w/ 1500 psi. Rotate 60 rpm w/ 6k ft lbs of torque. 09:15 09:30 0.25 2,916 2,916 INTRMI DRILL OWFF P Orient motor to high side. Blow down the top drive. Monitor well for flow - static. 09:30 10:15 0.75 2,916 2,916 INTRMI RIGMNT SVRG P Service rig, top drive and iron roughneck. Visual check of drilling line- looks good. 10:15 12:00 1.75 2,916 5,485 INTRM1 DRILL TRIP P Trip in the hole from 2613' to 5485'. PU wt 180k, SO wt 160k. Fill pipe every 20 stands. 12:00 12:45 0.75 5,485 7,483 INTRM1 DRILL TRIP P Continue to trip in the hole from 5485' to 7483'. PU wt 223k, SO wt 185k. 12:45 13:45 1.00 7,483 7,578 INTRM1 DRILL WASH P Make a top drive connection. Wash and ream to bottom whle circulating a bottom's up from 7483' to 7578'. Page 9 of 29 411110 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 00:00 10.25 7,578 8,011 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Drill motor (1.5 deg bend) from 7578' to 8011' (6650' TVD). Drill w/ 8 to 14k weight on bit. Pumping 625 gpm w/ 2480 to 2390 psi. Rotate 70 rpm w/ 11 k torque on bottom and 9k torque off bottom. Actual drilling time 5.88 hrs of which 4.79 hrs was sliding. PU wt 228k, SO wt 197k, Rot wt 215k. Note: Performed 275 bbl inhibycol dilution while drilling @ 7578'. 01/20/2010 Drill 8 -3/4" hole w/ Sperry Drill motor (1.5 deg bend) from 8011' to 9140' (6958.89' TVD) (TD of 8 -3/4" intermediate hole). Circulate while setting back a stand every 30 minutes from 9140' to 9006', Backream out f/ 9006' to 7864', pumping 600 gpm w/ 2080 psi, rotating 50 rpm w/ 10k ft Ibs of torque. ECD's 10.45 ppg. Pulling speed 17' /minute. 00:00 12:00 12.00 8,011 8,625 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Drill motor (1.5 deg bend) from 8011' to 8625' (6910' TVD). Drill w/ 5 to 16k weight on bit. Pumping 625 gpm w/ 2410 to 2510 psi. Rotate 70 rpm w/ 11.5 to 13k torque on bottom and 9 -10k torque off bottom. Actual drilling time 6.97 hrs of which 1.54 hrs was sliding. PU wt 240k, SO wt 188k, Rot wt 214k. 12:00 20:30 8.50 8,625 9,140 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ SperryDrill motor .. (10 (1.5 deg bend) from 8625' to 9140' (6959' TVD). Drill w/ 5 to 16k weight on bit. Pumping 625 to 635 gpm w/ 2480 to 2630 psi. Rotate 70 rpm w/ 11.5 to 14k torque on bottom and 10 to 10.5k torque off bottom. Actual drilling time 5.41 hrs of which 2.69 hrs was sliding. PU wt 244k, SO wt 185k, Rot wt 210k. 20:30 22:00 1.50 9,140 9,006 INTRM1 DRILL CIRC P Circulate two bottom's up while setting back a stand every 30 minutes, from 9140' to 9006'. Rotate 50 rpm w/ 10k ft Ibs of torque. Pumping 625 gpm w/ 2210 psi. ECD's 10.44 ppg. Pulling speed 2 -3 ' /minute. 22:00 00:00 2.00 9,006 7,864 INTRM1 DRILL REAM P Backream f/ 9006' to 7864'. Pumping 600 gpm w/ 2080 psi initial, 2080 psi final. Rotate 50 rpm w/ 10k ft Ibs initial torque and 9.5k ft Ibs final torque. Pulling speed 17' /minute. ECD's 10.45 ppg Page 10 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/21/2010 24 hr Summary Continue to backream out f/ 7864' to 7769', Circulate f/ 7769' to 7480', Trip in the hole f/ 7480' to 9100'. Wiped numerous areas from 8372' to 9100' (last stand tripped). Make a top drive connection, then ream from 9100' to 9140' (TD). Backream out from 9140' to 8435'. Re- reaming the hole which was wiped clean on trip in. Circulate from 8435' to 8244', Trip in the hole f/ 8244' to 9100'. Make a top drive connection, then ream from 9100' to 9140' (TD). Circulate hole clean,spot casing running pill, pump out laying in casing running pill f/ 9140' to 7769', monitor well- static, pull out of the hole f/ 7769' to 2650', circulate the 9 -5/8" casing clean, monitor well- static, blow down the top drive, pull out of the hole f/ 2650' to 733', monitor well- static, stand back 5" HWDP, lay down the jars, lay down three NM drill collars, drain SperryDrill motor, break hughes 8 -3/4" bit, download Sperry Sun MWD, lay down BHA #2. Pull FMC wear bushing. Make up BOP stack washing tool on a stand of 5" drill pipe, flush and clean stack, washing BOP ram cavities: pumping 650 gpm w/ 380 psi, jet pssum belly and flow line. Blow down the top drive, remove tool, set back a stand of 5" dp. Pre job safety meeting on changing top pipe rams. With blind rams closed, change top pipe rams from 3 -1/2" x 6" variable to 7 ". 00:00 00:15 0.25 7,864 7,769 INTRM1 DRILL REAM P Continue to backream out f/ 7864' to 7769', pumping 600 gpm w/ 2080 psi, rotating 60 rpm w/ 10.5k ft Ibs of torque. ECD's 10.45 to 10.49 ppg. Pulling speed 17' /minute. 00:15 02:00 1.75 7,769 7,480 INTRMI DRILL CIRC P Circulate while setting back a stand every 30 minutes (2 -3' /min) from 7769' to 7480'.Pumping 600 gpm w/ 2040 psi. Rotate 60 rpm w/ 10.5k ft Ibs of torque. Orient to high side after circulating. 02:00 02:15 0.25 7,480 7,578 INTRM1 DRILL TRIP P Trip in the hole f/ 7480' to 7578'. 02:15 02:30 0.25 7,578 7,578 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 02:30 03:30 1.00 7,578 9,100 INTRM1 DRILL TRIP P Trip in the hole f/ 7578' to 9100'. Wipe numerous areas from 8372' to 9100' (last stand tripped). Note: Area's which took weight while tripping in the hole: 8407', 8521', 8597', 8617', 8788', 8880', 8998'. 03:30 03:45 0.25 9,100 9,140 INTRM1 DRILL REAM P Make a top drive connection, then ream from 9100' to 9140' Pumping 625 gpm w/ 2180 psi. Rotate 50 rpm w/ 10.5k. PU wt 240k, SO wt 178k. 03:45 05:15 1.50 9,140 8,435 INTRMI DRILL REAM P Backream out from 9140' to 8435'. Pumping 600 gpm w/ 2030 psi. Rotating 50 rpm w/ 10.5k ft Ibs of torque. Pulling speed 17 to 20' /min. Note: Re- reaming the hole which was wiped clean on trip in. 05:15 05:45 0.50 8,435 8,244 INTRM1 DRILL CIRC P Circulate while setting back a stand every 30 minutes (2 -3' /min) from 8435' to 8244'. Pumping 600 gpm w/ 2030 psi. Orient motor to high side. 05:45 06:00 0.25 8,244 8,339 INTRM1 DRILL TRIP P Trip in the hole f/ 8244' to 8339'. Blow down the top drive. 06:00 06:15 0.25 8,339 9,100 INTRM1 DRILL TRIP P Trip in the hole f/ 8339' to 9100'. Hole is in good shape. 06:15 06:30 0.25 9,100 9,140 INTRMI DRILL REAM P Make a top drive connection, then ream from 9100' to 9140' Pumping 600 gpm w/ 2030 psi. Rotate 50 rpm w/ 10k. PU wt 240k, SO wt 178k. Page 11 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:00 1.50 9,140 9,140 INTRM1 DRILL CIRC P Circulate and condition mud and hole @ 9140'. Pumping 600 gpm w/ 2030 psi. Rotate 50 rpm w/ 10k ft Ibs of torque. 08:00 09:30 1.50 9,140 7,769 INTRMI DRILL TRIP P Spot casing running pill in the drill pipe. Pump out of the hole, pumping 105 gpm w/ 210 psi, while pulling to lay in the casing running pill from 9140' to 7769'. PU wt 242k, SO wt 178k. Note: Casing running pill: 95 bbls pumpable mixed with active mud, MW 9.8 ppg, Safe Carb 40, Safe Carb 250, G Seal, Alpine drill beads, Soltex, Resinex and IoTorq lube. 09:30 09:45 0.25 7,769 7,769 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 09:45 14:15 4.50 7,769 2,650 INTRM1 DRILL TRIP P Pull out of the hole from 7769' to 2650'. Monitor well on the trip tank. PU wt 150k, SO wt 175k. 14:15 14:30 0.25 2,650 2,650 INTRMI DRILL OWFF P Monitor well at the 9 -5/8" shoe - static. 14:30 15:15 0.75 2,650 2,650 INTRM1 DRILL CIRC P Circulate bottom's up to clean up casing and reduce yield point of mud. Pumping 600 gpm w/ 1520 psi. Rotate 30 rpm w/ 6k ft Ibs of torque. 15:15 15:30 0.25 2,650 2,650 INTRM1 DRILL OWFF P Monitor well- static. Blow down the top drive. 15:30 17:30 2.00 2,650 733 INTRMI DRILL TRIP P Pull out of the hole from 2650' to 733'. Monitor well on the trip tank. 17:30 17:45 0.25 733 733 INTRMI DRILL OWFF P Monitor well- static. Blow down the top drive. 17:45 18:30 0.75 733 175 INTRM1 DRILL TRIP P Stand back 6 stands of 5" HWDP, lay down the jars. 18:30 19:00 0.50 175 83 INTRMI DRILL PULD P Lay down (3) 6 -5/8" NM Drill collars. 19:00 19:15 0.25 83 83 INTRMI DRILL TRIP P Pick up, drain motor, break bit. 19:15 19:45 0.50 83 83 INTRM1 DRILL PULD P Download Sperry Sun MWD. 19:45 20:45 1.00 83 0 INTRMI DRILL PULD P Lay down BHA #2. 20:45 21:15 0.50 0 0 INTRMI DRILL OTHR P Pull FMC wear bushing, clear floor. 21:15 22:30 1.25 0 0 INTRMI DRILL CIRC P Make up stack washing tool on a stand of drill pipe. Wash BOP stack pumping 650 gpm w/ 380 psi. Jetting flow line and pssum belly at shakers. Cleaning up BOP ram cavities. 22:30 22:45 0.25 0 0 INTRMI DRILL TRIP P Drain stack, blow down the top drive. Set back stand. 22:45 23:00 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting on changing top pipe rams f/ 3 -1/2" x 6" variable to 7 ". 23:00 00:00 1.00 0 0 INTRMI WHDBO NUND P Close blinds. Change upper pipe rams (3 -1/2" x 6 ") to 7 ". Page 12 of 29 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/22/2010 24 hr summary C hangP top pipe rams to 7 ". PJSM. RU, test to 250 psi and 3500 psi, R/D test equip, install FMC thin wear bushing, PJSM, RU, PJSM, Run 7" csg: MU fist 4 jts, fill pipe w/ Frank's fillup tool, circ 20 bbls, check floats - OK. Con't to run 7 ". Avg MU torque 8000 ft lbs. The first 30 joints have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. Con't to run 7" csg f/ 1200' to 2630'. Circ & cond mud @ 2630'. Con't to run 7" f/ 2630' to 5065'. Between jt # 97 and # 98 is the Halliburton Type HES 7" stage collar (Baker locked). Centralizer floating on Jt # 97 & # 98 between a stop, 10' above and below cementer. Circ & cond mud © 5065'. Con't to run 7" f/ 5065' to 7507'. Centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. Circ & cond mud @ 7507'. Con't to run 7" f/ 7507' to 9130'. PU wt 300k, SO wt 175k. R/D Frank's FU tool. RU Dowell cement head & cementing hose. Circ a total of 693 bbls, PJSM. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll, Shut down, load bottom plug. Pump another 5 bbls of mudPushll @ 11.5 ppg. Shut down, load shut off plug. Mix & pump 56.7 bbls 15.8 ppq(273 sx) (1.16 cuft/sx) 5.076 qal /sx) cement @ 5.2 bpm avg w/ 400 psi initial and 140 psi final. Drop Halliburton shut off plug, chase w/ 20 bbls water pumping 5.3 bpm w/ 44 psi initial and -17 psi final pressure. Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Recip until 15.8 bbls before bumping plug, final rate 3 bpm, landed on FMC hanger. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. 00:00 00:30 0.50 0 0 INTRM1 WHDBO NUND P Continue to change upper pipe rams (3 -1/2" x 6 ") to 7 ". Blind rams are closed. 00:30 00:45 0.25 0 0 INTRM1 WHDBO BOPE P Pre job safety meeting on rigging up to test 7" rams. 00:45 01:00 0.25 0 0 INTRMI WHDBO BOPE P Rig up to test 7" rams. 01:00 01:15 0.25 0 0 INTRM1 WHDBO BOPE P Test 7" upper pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. 01:15 01:30 0.25 0 0 INTRM1 WHDBO BOPE P Blow down testing lines. Rig down. 01:30 02:00 0.50 0 0 INTRMI CASING PULD P Install FMC thin wear bushing (10.75" ID). Lay down the 7" test joint. 02:00 02:15 0.25 0 0 INTRM1 CASING SFTY P PJSM on rigging up casing running equipment. 02:15 02:45 0.50 0 0 INTRMI CASING RURD P Rig up to run 7" 26 ppf L -80 BTC -m casing. 02:45 03:00 0.25 0 0 INTRMI CASING SFTY P PJSM on running 7" 26 ppf L -80 BTC -m casing. 03:00 04:00 1.00 0 172 INTRMI CASING RNCS P Run 7" casing: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal 11 Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were bakerlocked. 04:00 04:15 0.25 172 172 INTRM1 CASING CIRC P Fill pipe w/ Frank's fillup tool, circulate 20 bbls, check floats- OK. Page 13 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 06:00 1.75 172 1,200 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTCM casing. Average make up torque 8000 ft lbs of torque. 30 jts in the hole. The first 30 joints all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. 06:00 07:30 1.50 1,200 2,630 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTCM casing from 1200' to 2630' (Jt # 30 to jt # 65). 07:30 08:15 0.75 2,630 2,630 INTRMI CASINGCIRC P Circulate and condition mud @ 2630', prior to exiting surface casing shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. 08:15 11:00 2.75 2,630 5,065 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTCM casing from 2630' to 5065' ( Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the 7" Halliburton Type HES cement stage tool. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and the box. A centralizer floating between the pin and 10' above the pin of joint # 98. Then centralizers were installed floating on jt # 99 to # 123. 11:00 12:00 1.00 5,065 5,065 INTRMI CASING CIRC P Circulate and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. 12:00 15:00 3.00 5,065 7,507 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTCM casing from 5065' to 7507' (Jt # 125 to jt # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. 15:00 16:30 1.50 7,507 7,507 INTRMI CASING CIRC P Circulate and condition mud @ 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. 16:30 19:00 2.50 7,507 9,130 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTCM casing from 7507' to 9130' (Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K PU wt to break over. Landed on hanger @ 1900 hrs. 19:00 19:15 0.25 9,130 9,130 INTRMI CASING RURD P Rig down Frank's fill up tool, blow down the top drive. 19:15 19:30 0.25 9,130 9,130 INTRMI CEMEN RURD P Rig up Dowell cement head and cementing hose. Page 14 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:45 2.25 9,130 9,130 INTRM1 CEMEN P Circulate, staging pumps f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. Pre job safety meeting while circulating. Circulated a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg 21:45 22:30 0.75 9,130 9,130 INTRM1 CEMEN" PUCM P Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial to 190 psi final. Shut down, then load bottom plug. Pump another 5 bbls of 11.5 ppg mudPushll. Shut down and load shut off plug. 22:30 22:45 0.25 9,130 9,130 INTRM1 CEMEN" PUCM P Dowell mix and pump 56.7 bbls (273 sx) Alpine tail cement (15.8 ppg) (1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 400 psi initial and 140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pumping 4.5 to 5.3 bpm w/ 44 psi to -17 psi. 22:45 23:45 1.00 9,130 9,130 INTRM1 CEMEN" DISP P Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Reciprocated f/ 9130' to 9120' until 15.8 bbls before bumping plug, landed on FMC hanger. Slowed to 3 bpm for the last 20 bbls pumped. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. 23:45 00:00 0.25 9,130 9,130 INTRM1 CEMEN - OTHR P Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. Page 15 of 29 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/23/2010 24 hr summary Estab circ thru Halliburton 7" HES stage tool at 5192.67'. Pump 6 bpm w/ 270 psi. PJSM on 2nd stage cement job while circ 6 bpm w/ 250 psi final. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial - 220 psi final. Shut down. Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 ppg) (1.17 cuft/sx yield) (5.105 gal /sx water) (5.34 hrs thickening time). Pump 5.2 bpm average w/ 260 psi initial -150 psi final pressure. Drop Halliburton closing plug, chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displace cement w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final, bumped plug at calculated strokes (1779 strokes). Pressure to 1100 psi, bled off pressure, tool not shut. Re- pressure to 1500 psi, tool shut at 1425 psi. Bumped plug @ 0209 hrs 1 -23 -2010. Held pressure 4 minutes, bled off pressure. R/D cement head and hose. UD 7" landing joint. PU/ MU wear ring pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. UD running tool. Torque lockdown screws to 450 ft lbs. Test 7" packoff to 5000 psi for 10 min. UD 7" csg equip. PJSM,change top pipe rams to 3 -1/2" x 6, change saver sub to 4" XT 39. PJSM, RU to test, Test BOPE: Everything to 250 psi low, annular to 2500 psi high, all other components to 3500 psi high, chart all tests. Hold each test 5 minutes. Tested accumulator. Witness of test waived by AOGCC inspector Chuck Scheve. Tested BOPE w/ 3 -1/2 ", 4 ", and 4 -1/2" test ioint. Pull 4 -1/2" test joint and test plug, blow down kill and choke lines, blow choke manifold, install FMC (7 -1/8" ID) wear bushing, PJSM, Pick up/ stand back 4" drill pipe in the derrick, via the mousehole. 00:00 00:30 0.50 9,130 9,130 INTRM1 CEMEN"CIRC P Establish circulation through the Halliburton 7" HES stage tool at 5192.67'. Pumping 6 bpm w/ 270 psi. 00:30 00:45 0.25 9,130 9,130 INTRMI CEMEN" SFTY P Pre job safety meeting on 2nd stage cement job while continuing to circulate. 00:45 01:00 0.25 9,130 9,130 INTRMI CEMEN "CIRC P Circulate, pumping 6 bpm w/ 250 psi final. Circulated a total of 332 bbls. No indication of CW100 or mud push at the shakers. 01:00 01:15 0.25 9,130 9,130 INTRMI CEMEN" PUCM P Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial and 220 psi final. Shut down. 01:15 01:30 0.25 9,130 9,130 INTRMI CEMEN" PUCM P Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 260 psi initial and 150 psi final pressure. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pumping 5.2 bpm w/ 70 psi. Page 16 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:15 0.75 9,130 9,130 INTRM1 CEMEN" DISP P Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm w/ 140 psi initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final prior to bumping plug at calculated strokes (1779 strokes). Pressured to 1100 psi, bled off pressure, tool not shut. Re- presure to 1500 psi, tool shut at 1425 psi. Bumped plug @ 0209 hrs 1 -23 -2010. Held pressure 4 minutes, bled off pressure. 02:15 03:30 1.25 9,130 0 INTRMI CEMEN" RURD P Rig down cement head and hose. Lay down 7" landing joint. 03:30 04:15 0.75 0 0 INTRM1 DRILL OTHR P Pick up/ make up wear rig pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. Lay down the running tool. Torque the lower lockdown screws to 450 ft Ibs of torque. 04:15 04:30 0.25 0 0 INTRM1 DRILL PRTS P Test the 7" packoff to 5000 psi for 10 minutes. Witness of test by FMC Bobby and Rig Supervisor. 04:30 05:00 0.50 0 0 INTRMI DRILL PULD P Lay down 7" casing equipment. 05:00 05:15 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams from 7" to 3 -1/2" x 6" variables. 05:15 06:30 1.25 0 0 INTRM1 WHDBO NUND P With blinds shut. Change upper pipe rams to 3 -1/2" x 6" variables. Also changing saver sub on the top drive from 4 -1/2" IF to 4" XT 39 06:30 06:45 0.25 0 0 INTRMI DRILL SFTY P Pre job safety meeting on rig up to lay down 5" drill pipe f/ derrick. 06:45 07:15 0.50 0 0 INTRM1 DRILL RURD P Install drilling bales on the top drive. Install 5" elevators. 07:15 12:30 5.25 0 0 INTRMI DRILL PULD P Lay down 5" drill pipe from the derrick via the mouse hole. A total of 59 stands were layed down, leaving 30 stands of 5" in the derrick for the next hole. 12:30 13:00 0.50 0 0 INTRM1 DRILL PULD P Lay down 5" drilling tools, pick up 4" drilling tools. 13:00 13:15 0.25 0 0 INTRMI DRILL SFTY P Pre job safety meeting on moving hi -line cable to the rig. 13:15 13:45 0.50 0 0 INTRM1 DRILL RURD P Rig went off hi -line at 1300 hrs, back on at 1415 hrs. Disconnect Hi -line cable, re -route cable due to construction activities on pad. 13:45 14:00 0.25 0 0 INTRMI DRILL SFTY P Pre job safety meeting on slip and cut drilling line. Page 17 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:15 1.25 0 0 INTRMI RIGMNT SVRG P Hang blocks. Slip and cut 60' of 1 -3/8" drilling line. Service the top drive. 15:15 15:45 0.50 INTRM1 RIGMNT SVRG P Change the 5" die blocks on the iron roughneck to 4 ". Adjust air pressure on the top drive. 15:45 17:15 1.50 0 0 INTRMI WHDBO RURD P Set FMC upper test plug. Rig up to test BOPE. 17:15 22:30 5.25 0 0 INTRM1 WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Rig electrician tested floor methane alarm and pit H2S alarm- good. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 3 -1/2 ", 4" and 4 -1/2" test joint. Accumulator test performed: initial pressure 3000 psi, 1650 psi after operating. Recovery time test of 34 seconds for 200 psi build up and 2 minutes 43 seconds for full charge. Nitrogen bottles average 1675 psi. 22:30 23:00 0.50 0 0 INTRM1 WHDBO OTHR P Remove FMC upper test plug. Blow down kill and choke lines, blow down chioke manifold. Set FMC 7 -1/8" ID wear bushing. 23:00 23:15 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on picking up and standing back in the derrick 10 stands of 4" drill pipe. 23:15 00:00 0.75 0 0 INTRMI DRILL PULD P Pick up/ make up/ stand back 4" drill pipe in the derrick, via the mouse hole. Note: Performed injectivity test, flush and freeze protected 9 -5/8" x7" annulus on CD3 -122 with dowell on 1 -23 -2010. Injectivity test 7 bbls 9.8 ppg mud, 300 bbls water, 50 bbls diesel. Page 18 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/24/2010 24 hr summary Continue to pick up/ stand back 4" drill pipe in the derrick (10 stands total) via the mousehole, make up BHA #3 to clean out 7 ", pick up 4" drill pipe from the pipe shed, single in the hole f/ 309' to 5080', rig up then test csg to 1000 psi f/ 10 minutes. Wash /Drill down f/ 5080', drill cement to stage collar at 5192', drill stage collar, wash /Drill f/ 5195' to 5559', Rig up then test casing to 1000 psi f/ 10 minutes, continue to PU 4" dp /MU RIH w/ BHA #3 f/ 5559' to 8715', Wash /drill down f/ 8715' to 8734', tag cement @ 8734', Rig up then test casing to 3500 psi f/ 30 minutes, rig down equipment, wash /drill from top of cement to 7" baffle collar @ 8997', drill cement to the Halliburton Sure Seal II float collar @ 9042', then drill more cement to 10' above the shoe (drilled to 9120'). Circulate bottom's up twice, pump a dry job, pull out of the hole on elevators f/ 9120' to 4889'. Note: Performed infectivity test, flush and freeze protected 9 -5/8" x7" annulus on CD3 -122 with dowel) on 1 -23 -2010. Injectivity test 7 bbls 9.8 ppg mud, 300 bbls water, 50 bbls diesel. Total of 357 bbls pumped by Dowell. 00:00 00:15 0.25 0 0 INTRMI DRILL PULD P Continue to pick up/ stand back 4" drill pipe in the derrick (10 stands total), via the mousehole. 00:15 02:00 1.75 0 309 INTRM1 DRILL PULD P Make up BHA #3 to clean out 7 ". Make and break new HWDP. 02:00 06:45 4.75 309 5,080 INTRMI DRILL PULD P Pick up/ RIH w/ 4" drill pipe on BHA #3 from 309' to 5080'. Fill pipe every 20 stands. 06:45 07:30 0.75 5,080 5,080 INTRM1 DRILL PRTS P Rig up, test casing to 1000 psi f/ 10 minutes, rig down testing equipment 07:30 08:15 0.75 5,080 5,192 INTRMI CEMEN" COCF P Wash /Drill from 5080' to stage collar @ 5192'. Pumping 60253 gpm w/ 1100 psi, then 300 gpm w/ 1460 psi. Rotate 35 rpm w/ 6.5k ft Ibs of torque 08:15 08:45 0.50 5,192 5,195 INTRMI CEMEN" DRLG P Drill stage collar f/ 5192' to 5195'. Pumping 300 gpm w/ 1400 psi. Rotate 30 rpm. Motor turning 231 rpm + 30 rpm = 261 rpm bit speed. 08:45 09:30 0.75 5,195 5,559 INTRMI CEMEN" DRLG P Wash /Drill from 5195' to 5559'. 09:30 10:15 0.75 5,559 5,559 INTRM1 DRILL PRTS P Rig up, test casing to 1000 psi f/ 10 minutes, rig down testing equipment. 10:15 13:15 3.00 5,559 8,715 INTRM1 DRILL PULD P Continue to pick up/ RIH w/ 4" drill pipe on BHA #3 from 5559' to 8715'. Fill pipe every 20 stands. 13:15 14:30 1.25 8,715 8,734 INTRM1 CEMEN" DRLG P Wash /Drill from 8715' to 8734', Baffle collar @ 8997.93'. Pumping 250 gpm w/ 1470 psi. Rotate 35 rpm w/ 10k ft Ibs of torque. Tag cement @ 8734'. 14:30 14:45 0.25 8,734 8,734 INTRM1 DRILL SFTY P Blow down the top drive. Pre job safety meeting . 14 :45 15:00 0.25 8,734 8,734 INTRM1 DRILL PRTS P Rig up to test casing to 3500 psi f/ 30 minutes. 15:00 15:45 0.75 8,734 8,734 INTRM1 DRILL PRTS P Test casing to 3500 psi f/ 30 minutes. Good test 15:45 16:00 0.25 8,734 8,734 INTRMI DRILL PRTS P Bleed off pressure. Blow down lines. Page 19 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 19:15 3.25 8,734 9,120 INTRM1 CEMEN" COCF P Wash /drill from 8734' (Top of cement) to the baaffle collar © 8997', then drill cement to the Halliburton Sure Seal 11 float collar @ 9042', then more cement to 9120' (10' above the bottom of Ray Oil Tool silver bullet eccentric shoe). Pumping 300 gpm w/ 2120 psi, rotate 35 rpm w/ 11.5 ft lbs of torque. Motor turning 231 rpm + rotary 35 = 266 rpm 19:15 20:30 1.25 9,120 9,120 INTRM1 DRILL CIRC P Circulate bottom's up twice. Pumping 300 gpm w/ 1980 psi. Rotate string 35 rpm w/ 11.5k ft Ibs of torque. Motor turning 231 rpm + rotary 35 = 266 rpm 20:30 20:45 0.25 9,120 9,120 INTRMI DRILL CIRC P Pump a dry job. Blow down the top drive. 20:45 00:00 3.25 9,120 4,889 INTRM1 DRILL TRIP P Pull out of the hole on elevators from 9120' to 4889'. Monitor well on the trip tank. PU wt 165k. 01/25/2010 Continue to pull out of the hole on elevators f/ 4889' w/ BHA #3, work and UD BHA #3. PU /MU BHA #4 (GeoPilot assembly), PJSM, Load Nuke Sources, PU /MU run in 183 jts of 4" dp from pipe shed to 6233', continue RIH from the derrick to 9099', precautionary ream 9099' to top of cement @ 9120', drill cement to Ray Oil Tool float shoe (top @ 9128'- bottom @ 9130', clean out rat hole to 9140', drill 20' new hole to 9160', circulate, perform FIT to 12.6 poa EMW, PJSM, displace to 9.0oDa Flo -Thru mud. Monitor well- static, obtain slow pump rates and parameters, drill 6 -1/8" hole w/ Sperry Sun GeoPilot from 9160' to 9290' at midnight. 00:00 01:45 1.75 4,889 123 INTRM1 DRILL TRIP P Continue to pull out of the hole on elevators from 4889' to 123' . Monitor well on the trip tank. 01:45 02:30 0.75 123 0 INTRM1 DRILL TRIP P Stand back non mag drill collars. Lay down BHA #3. 02:30 04:45 2.25 0 121 INTRM1 DRILL PULD P Pick up/ Make up BHA #4 (geoPilot). 04:45 05:45 1.00 121 121 INTRMI DRILL PULD P Upload MWD. 05:45 06:00 0.25 121 121 INTRM1 DRILL DHEQ P Shallow test MWD (a7 121'. 06:00 06:15 0.25 121 121 INTRM1 DRILL SFTY P Pre job safety meeting on loading Nuke Sources. 06:15 06:45 0.50 121 121 INTRMI DRILL PULD P Sperry Sun load Nuke sources. 06:45 12:00 5.25 121 5,469 INTRMI DRILL PULD P Pick up/ Make up 4" HWDP from the pipe shed, then picking up 4" drill pipe from shed and single in on top of BHA #4 to 5469'. Fill pipe every 20 stands. 12:00 12:30 0.50 5,469 6,233 INTRMI DRILL PULD P Continue picking up 4" drill pipe from shed and single in on top of BHA #4 to 6233'. Fill pipe every 20 stands. Picked up a total of 183 jts. PU wt 180k, SO wt 140k. 12:30 14:30 2.00 6,233 9,099 INTRM1 DRILL TRIP P Trip in w/ BHA #4 (GeoPilot). Running drill pipe from the derrick from 6233' to 9099'. PU wt 250k, SO wt 140k. Page 20 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 15:00 0.50 9,099 9,120 INTRMI DRILL WASH P Precautionary wash down from 9099' to top of cement @ 9120'. Break in seals on the GeoPilot. Pumping 200 gpm w/ 1650 psi. Rotate 90 rpm w/ 12k ft Ibs of torque. 15:00 15:30 0.50 9,120 9,130 INTRMI CEMEN" DRLG P Drill cement from 9120' to Rays Silver Bullet eccentric shoe @ 9128 to 9130'. Pumping 200 gpm w/ 1650 psi. Rotate 90 rpm w/ 12k ft Ibs of torque. Drill w/ 5k weight on bit. PU wt 250k, SO wt 140k, Rot wt 170k. 15:30 16:00 0.50 9,130 9,140 INTRM1 CEMEN" DRLG P Continue drilling from 9130' to 9140' (rat hole). Pumping 200 gpm w/ 1650 psi. Rotate 90 rpm w/ 12k ft Ibs of torque. Drill w/ 5k weight on bit. PU wt 250k, SO wt 140k, Rot wt 170k. 16:00 16:30 0.50 9,140 9,160 INTRM1 DRILL DDRL P Drill 20' of new hole from 9140' to 9160' (TVD 6960'). Pumping 160 gpm w/ 1050 psi. Rotate 90 rpm w/ 14k ft Ibs of torque. ECD's 10.50. Drill w/ 8k weight on bit. PU wt 210k, SO wt 175k, Rot wt 184k. Actual drilling time .61 hrs. 16:30 17:15 0.75 9,160 9,160 INTRM1 DRILL CIRC P Circulate and condition mud for FIT /LOT. Pumping 170 gpm w/ 2230 psi. Rotate 35 rpm w/ 12k ft lbs of torque. ECD's 10.34 17:15 17:45 0.50 9,160 9,160 INTRM1 DRILL RURD P Blow down the top drive. Rig up to perform FIT /LOT. 17:45 18:00 0.25 9,160 9,160 INTRM1 DRILL FIT P Perform FIT. Mud wt 9.8 ppg, applied , /, \\ pressure 1020 psi. TVD of 7" casing shoe 6958.3'. FIT to 12.6 DDa. 18:00 18:15 0.25 9,160 9,160 PROD1 DRILL RURD P Rig down testing equipment. 18:15 18:30 0.25 9,160 9,160 PROD1 DRILL SFTY P Pre job safety meeting on displacing 9.8 ppg mud to 9.0 ppg Flow-Thru mud. 18:30 19:30 1.00 9,160 9,160 PROD1 DRILL CIRC P Displace well to 9.0 ppg Flow -Thru. Pumping 200 gpm w/ 1750 psi. Rotate 60 rpm w/ 11.5k ft Ibs of torque. Pumped 40 bbls SafeKleen then 40 bbls viscosified Flo -Thru, then 9.0 ppg Flo -Thru. 19:30 19:45 0.25 9,160 9,160 PROD1 DRILL CIRC P Obtain slow pump rates: #1: 20 spm 580 psi, 30 spm 860 psi, #2: 20 spm 580 psi, 30 spm 860 psi. 19:45 20:15 0.50 9,160 9,160 PROD1 DRILL OWFF P Monitor well f/ flow- static. Obtain parameters: PU wt 200k, SO wt 165k, Rot wt 184k. Pumping 198 gpm (47 spm) w/ 1650 psi, with pumps on Rotating wt 174k, 60 rpm w/ 8k ft Ibs of torque. ECD's 10.3 ppg Page 21 of 29 II • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 00:00 3.75 9,160 9,290 PROD1 DRILL DDRL P Drill 6 -1/8" hole w/ bottom hole assembly # 4 (Geopilot ser # TL089, w/ 6 -1/8" Security DBSFSF3543ZZ bit, ser # 11271559) from 9160' to 9290' (6968' TVD). Drill w/ 5 -12k weight on bit. Pumping 200 gpm w/ 1690 to 1490 psi. Rotate 90 to 120 rpm w/ 10k ft Ibs of torque on bottom and 8k ft Ibs off bottom. ECD's 10.4 to 10.36 ppg. PU wt 202k, SO wt 162k, Rot wt 184k. Actual drilling time 2.5 hrs. 01/26/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot from 9290' to 10722'. 00:00 06:00 6.00 9,290 9,636 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 9290' to 9636' (6963' TVD). Actual drilling time 5.09 hrs. Drill w/ 6 -16k weight on bit. Pumping 200 to 220 gpm w/ 1390 to 1700 psi. Rotate 120 rpm w/ 1- to 9.5k ft Ibs of torque on bottom and 8k ft Ibs off bottom. ECD's 10.45 ppg. PU wt 202k, SO wt 158k, Rot wt 183k. Note: Significant foaming of mud while drilling f/ 9385 to 9671'. Added de foamer. 06:00 12:00 6.00 9,630 9,958 PROD1 DRILL DDRL P Drill 6 -1/8" from 9636' to 9958' (6970' TVD). Actual drilling time 4.41 hrs. Drill w/ 11 -14k weight on bit. Pumping 210 to 205 gpm w/ 1680 to psi. Rotate 120 rpm w/ 9.5 to 10k ft Ibs of torque on bottom and 7.5k ft Ibs off bottom. ECD's 10.5 ppg. PU wt 200k, SO wt 160k, Rot wt 180k. 12:00 18:00 6.00 9,958 10,340 PROD1 DRILL DDRL P Drill 6 -1/8" from 9958' to 10340' (6977 TVD). Actual drilling time 4.72 hrs. Drill w/ 8 -17k weight on bit. Pumping 205 gpm w/ 1740 psi. Rotate 120 rpm w/ 9.5k ft Ibs of torque on bottom and 7k ft Ibs off bottom. ECD's 10.50ppg. PU wt 203k, SO wt 160k, Rot wt 183k. 18:00 00:00 6.00 10,340 10,722 PROD1 DRILL DDRL P Drill 6 -1/8" from 10340' to 10722' (6983' TVD). Actual drilling time 4.55 hrs. Drill w/ 8 -17k weight on bit. Pumping 205 gpm w/ 1740 psi. Rotate 120 rpm w/ 9.5k ft Ibs of torque on bottom and 7k ft Ibs off bottom. ECD's 10.50ppg. PU wt 203k, SO wt 160k, Rot wt 183k. Note: Slight seepage losses: loss of 74 bbls to the formation today. Performed 275 bbls dilutions while drilling at 9870' and 10627'. 01/27/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot from 10722' to 11996'. Note: Slight seepage losses: loss of 102 bbls to the formation today. Total losses for the well equals176 bbls. Performed 275 bbls mud dilutions while drilling at 11200' and 11774'. Page 22 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 10,722 11,065 PROD1 DRILL DDRL P Drill 6 -1/8" from 10722' to 11065' (6988' TVD). Actual drilling time 4.82 hrs. Drill w/ 10 -14k weight on bit. Pumping 200 gpm w/ 1740 psi. Rotate 120 rpm w/ 10k ft Ibs of torque on bottom and 7.5k ft Ibs off bottom. ECD's 10.54 ppg. PU wt 205k, SO wt 157k, Rot wt 182k. 06:00 12:00 6.00 11,065 11,369 PROD1 DRILL DDRL P DriII6 -1/8 "from 11065'to 11369' (6986' TVD). Actual drilling time 4.41 hrs. Drill w/ 8 -12k weight on bit. Pumping 200 gpm w/ 1660 psi. Rotate 120 rpm w/ 10k ft Ibs of torque on bottom and 7.5k ft Ibs off bottom. ECD's 10.50 ppg. PU wt 205k, SO wt 155k, Rot wt 182k. 12:00 18:00 6.00 11,369 11,678 PROD1 DRILL DDRL P Drill 6 -1/8" from 11369' to 11678' (6988' TVD). Actual drilling time 4.94 hrs. Drill w/ 6 -10k weight on bit. Pumping 195 gpm w/ 1710 psi. Rotate 120 rpm w/ 9.5k ft Ibs of torque on bottom and 7.5k ft Ibs off bottom. ECD's 10.43 ppg. PU wt 207k, SO wt 152k, Rot wt 183k. 18:00 00:00 6.00 11,678 11,996 PROD1 DRILL DDRL P Drill 6 -1/8" from 11678' to 11996' (6990' TVD). Actual drilling time 4.41 hrs. Drill w/ 6 -15k weight on bit. Pumping 195 to 200 gpm w/ 1710 to 1800 psi. Rotate 120 rpm w/ 9.5 to 11.5k ft Ibs of torque on bottom and 7.5 to 9k ft Ibs off bottom. ECD's 10.5 ppg. PU wt 210k, SO wt 152k, Rot wt 183k. Note: Slight seepage losses: loss of 102 bbls to the formation today. Total losses for the well equals176 bbls. Performed 275 bbls dilutions while drilling at 11200' and 11774'. 01/28/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot from 11996' to 13400'. Note: Slight seepage losses: loss of 261 bbls to the formation today. Total losses for the well equals 437 bbls. Performed 275 bbls mud dilutions while drilling at 12348', 12750' and 13326'. 00:00 06:00 6.00 11,996 12,377 PROD1 DRILL DDRL P Drill 6 -1/8" from 11996' to 12377' (6992' TVD). Actual drilling time 5.03 hrs. Drill w/ 7 to 15k weight on bit. Pumping 200 gpm w/ 1710 to 1750 psi. Rotate 120 rpm w/ 11.5k ft Ibs of torque on bottom and 9k ft Ibs off bottom. ECD's 10.47 ppg. PU wt 210k, SO wt 152k, Rot wt 183k. 06:00 12:00 6.00 12,377 12,731 PROD1 DRILL DDRL P Drill 6 -1/8" from 12377' to 12731' (6998' TVD). Actual drilling time 4.47 hrs. Drill w/ 8 to 12k weight on bit. Pumping 200 gpm w/ 1720 psi. Rotate 120 rpm w/ 11.5k ft Ibs of torque on bottom and 9k ft Ibs off bottom. ECD's 10.4 ppg. PU wt 214k, SO wt 148k, Rot wt 182k. Page 23 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 12,731 13,121 PROD1 DRILL DDRL P Drill 6 -1/8" from 12731' to 13121' (6998' TVD). Actual drilling time 4.73 hrs. Drill w/ 9 to 15k weight on bit. Pumping 205 gpm w/ 1650 to 1820 psi. Rotate 120 rpm w/ 12.5k ft Ibs of torque on bottom and 9.5k ft Ibs off bottom. ECD's 10.47 ppg. PU wt 218k, SO wt 145k, Rot wt 184k. 18:00 00:00 6.00 13,121 13,400 PROD1 DRILL DDRL P Drill 6 -1/8" from 13121' to 13400' (7006' TVD). Actual drilling time 4.35 hrs. Drill w/ 8 to 14k weight on bit. Pumping 200 gpm w/ 1740 to 1680 psi. Rotate 120 rpm w/ 13k ft Ibs of torque on bottom and 10k ft Ibs off bottom. ECD's 10.5 ppg. PU wt 223k, SO wt 140k, Rot wt 183k. 01/29/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPiiot from 13400' to 13687'. Phase III weather, circulate and reciprocate from 13687' to 13595'. Continue to drill once weather went to Phase II at 1500 hrs from 13687' to 14080'. Note: Slight seepage losses: loss of 238 bbls to the formation today. Total losses for the well equals 675 bbls. Performed 275 bbls mud dilution while drilling at 13750'. 00:00 05:00 5.00 13,400 13,687 PROD1 DRILL DDRL P Drill 6 -1/8" from 13400' to 13687' (7015' TVD). Actual drilling time 4.24 hrs. Drill w/ 6 to 13k weight on bit. Pumping 198 to 190 gpm w/ 1750 to 1670 psi. Rotate 120 rpm w/ 12.5k ft Ibs of torque on bottom and 10k ft lbs off bottom. ECD's 10.47 ppg. PU wt 222k, SO wt 140k, Rot wt 183k. 05:00 07:15 2.25 13,687 13,687 PROD1 DRILL CIRC T Phase III weather. Circulate and backream slow, reciprocate from 13687' to 13595'. Pumping 193 gpm w/ 1700 psi. Rotate 120 rpm w/ 11k ft Ibs of torque. Circulated 3 bottom's up. 07:15 15:00 7.75 13,687 13,687 PROD1 DRILL CIRC T Phase III weather. Circulate and backream slow, reciprocate from 13687' to 13595'. Pumping 180 gpm w/ 1390 psi. Rotate 45 rpm w/ 10.5k ft Ibs of torque. 15:00 18:00 3.00 13,687 13,839 PROD1 DRILL DDRL P Drill 6-1/8" from 13687' to 13839' (7019' TVD). Actual drilling time 2.4 hrs. Drill w/ 6 to 13k weight on bit. Pumping 198 to 190 gpm w/ 1750 to 1670 psi. Rotate 120 rpm w/ 12.5k ft Ibs of torque on bottom and 10k ft Ibs off bottom. ECD's 10.47 ppg. PU wt 222k, SO wt 140k, Rot wt 183k. Note: Performed 275 bbls dilution while drilling at 13750'. Page 24 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 13,839 14,080 PROD1 DRILL DDRL P Drill 6 -1/8" from 13839' to 14080' (7022' TVD). Actual drilling time 4.26 hrs. Drill w/ 6 to 13k weight on bit. Pumping 198 to 190 gpm w/ 1750 to 1670 psi. Rotate 120 rpm w/ 12.5k ft Ibs of torque on bottom and 10k ft Ibs off bottom. ECD's 10.47 ppg. PU wt 222k, SO wt 140k, Rot wt 183k. Note: Slight seepage losses: loss of 238 bbls to the formation today. Total losses for the well equals 675 bbls. 01/30/2010 Continued to Drill 6 1/8" Hole w/ Geo -Pilot f/ 14,080' - 15,216' MD; Mud Lost to Hole in Previous 24 Hours = 268 Bbl; Total Mud Lost to Hole for Interval = 943 Bbl 00:00 06:00 6.00 14,080 14,357 PROD1 DRILL DDRL P Drilled 6 1/8" Hole w/ GeoPilot f/ 14,080' - 14,357' MD P/U 228, S/O 136, Rot 184 RPM 120, Torque On /Off 13,500/11,500 175 GPM @ 1480 Psi; ECD = 10.55 06:00 12:00 6.00 14,357 14,644 PROD1 DRILL DDRL P Drilled 6 1/8" Hole w/ GeoPilot f/ 14,357' - 14,644' MD P/U 230, S/O 133, Rot 185 RPM 120, Torque On /Off 13,500/11,500 175 GPM @ 1560 Psi; ECD = 10.50 12:00 18:00 6.00 14,644 14,942 PROD1 DRILL DDRL P Drilled 6 1/8" Hole w/ GeoPilot f/ 14,644' - 14,942' MD P/U 235, S/O 125, Rot 185 RPM 120, Torque On /Off 15,000/11,500 175 GPM @ 1530 Psi; ECD = 10.50 18:00 00:00 6.00 14,942 15,216 PROD1 DRILL DDRL P Drilled 6 1/8" Hole w/ GeoPilot f/ 14,942' - 15,216' MD P/U 228, S/O 136, Rot 184 RPM 120, Torque On /Off 15,000/11,500 175 GPM @ 1550 Psi; ECD = 10.56 01/31/2010 • Continued to Drill 6 1/8" Hole w/ Geo -Pilot f/ 15,216' - 15,409' MD; CBU X3 While Standing Back 1 Stand Every Hour t/ 15,026' MD; BROOH t/ 9,099' MD; Mud Lost to Hole in Previous 24 Hours = 132 Bbl; Total Mud Lost to Hole for Interval = 1075 Bbl 00:00 04:45 4.75 15,216 15,409 PROD1 DRILL DDRL P Continue Drilling 6 1/8" Hole f/ Geo -Pilot f/ 15,216' - 15,409' MD P/U 242, S/O 112, Rot 184 Torque On /Off 14,000/12,000 @ 120 RPM 180 GPM @ 1630 Psi; ECD = 10.5 04:45 09:15 4.50 15,409 15,026 PROD1 DRILL CIRC P CBU X3; 195 GPM @ 1670 Psi w/ 100 RPM - Stand Back 1 Stand Every Hour t/ 15,026' MD - OWFF (Well Breathing) Page 25 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 12:30 3.25 15,026 13,605 PROD1 DRILL REAM P BROOH t/ 13,065' MD; 190 GPM @ 1580 Psi w/ 100 RPM 12:30 13:00 0.50 13,605 13,605 PROD1 RIGMNTSVRG P Service Rig 13:00 00:00 11.00 13,605 9,099 PROD1 DRILL REAM P Continue to BROOH t/ 9,099' MD; 195 GPM @ 1500 Psi w/ 100 RPM Tight Spot 9,965' - 9,970' MD - Pulled 25K Over and Set 30K Down, Worked Through Spot w/ Rotary and then Verified Clean W/O Rotarty in Both Directions - Tight Spot Correlates w/ "Hard Spot" in DD Notes f/ 9,963 - 9,973' MD and Formation Change in Denisity Logs 02/01/2010 At the Shoe CBU X3 - OWFF (Flowing) - Displace to 9.2 PPG KCL Brine - OWFF (Static 1 BPH Loss) - POOH on TT t/ 415' MD - UD BHA #4 - R/U and Run Liner per Detail t/ 3,685' MD 00:00 00:30 0.50 9,099 9,099 PROD1 DRILL OWFF P OWFF - Flowing "Ooze" 00:30 03:00 2.50 9,099 9,099 PROD1 DRILL CIRC P CBU X3 03:00 03:15 0.25 9,099 9,099 PROD1 DRILL OWFF P OWFF - Flowing "Ooze" 03:15 04:30 1.25 9,099 9,099 PROD1 DRILL CIRC P Displace 9.0 ppg Flo Thru mud system to 9.2 ppg KCL brine. 04:30 05:00 0.50 9,099 9,099 PROD1 DRILL OWFF P OWFF - Static - R/U Hole Fill, Fill Pits & Prepare to POOH - Hole Losing 1 BPH Static 05:00 11:00 6.00 9,099 415 PROD1 DRILL TRIP P POOH on TT t/ 415' MD 11:00 15:30 4.50 415 0 PROD1 DRILL PULD P UD HWDP, Remove Nuclear Sources, Read MWD Data & UD the Remainder of BHA #4 15:30 16:00 0.50 0 0 PROD1 DRILL OTHR P Clean & Clear the Rig Floor 16:00 16:30 0.50 0 0 COMPZ CASING RURD P R/U to Run Lower Completion 16:30 00:00 7.50 0 3,685 COMPZ CASING RUNL P Run Lower Completion t/ 3685' MD as Follows: Float Shoe, 1 Jt 3 1/2" EUE Tubing, XO, 24 Jts 3 1/2" SLHT Tubing, Reslink Screen w/ Baker Ball Actuated Sleeve (1.525" ID), 22 Jts of SLHT Tubing, TAM Swell Packer, 10 Jts SLHT Tubing, Reslink Screen w/ Baker Ball Actuated Sleeve (1.65" ID), 12 Jts SLHT Tubing, TAM Swell Packer, 14 Jts SLHT Tubing, Reslink Screen w/ Baker Ball Actuated Sleeve (1.775" ID), 13 Jts SLHT Tubing, TAM Swell Packer, 14 JTs SLHT Tubing, Reslink Screen w/ Baker Ball Actuated Sleeve (1.90" ID) All Connections Torqued to 4,000 Ftlbs 02/02/2010 Continue to RIH w/ Lower Completion t/ 9,069' MD - Circ Tubing Volume @ the Shoe - Continue to Run Lower Completion t/ 15,409' MD - Space Out and Hang Lower Completion w/ Tail @ 15,399' MD - Inflate Packer and Release Hanger - Wait on Weather Phase 3 Page 26 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:45 4.75 3,685 6,687 COMPZ CASING RUNL P Continue to Run Lower Completion t/ 6,687' MD as Follows: 13 Jts SLHT Liner, TAM Swell packer, 14 Jts SLHT Liner, Reslink Screens w/ Baker Ball Actuated Sleeve (2.025" ID), 12 Jts SLHT Liner, TAM Swell Packer, 19 Jts SLHT Liner, Reslink Screens w/ Baker Ball Actuated Sleeve (2.15" ID), 32 Jts SLHT Tubing, XO, Baker Seal Bore Extension, Baker Flex Lock Liner Hanger, RS Nipple, Baker ZXP Liner Top Packer 04:45 05:30 0.75 6,687 6,687 COMPZ CASING OTHR P Mix and Apply Pal -Mix to ZXP PAcker Top then Allow to Cure for 30 Minutes 05:30 06:00 0.50 6,687 6,779 COMPZ CASING CIRC P M/U 1 Stand 4" DP and Circulate a Tubing Volume @ 4 BPM w/ 630 Psi 06:00 08:15 2.25 6,779 9,069 COMPZ CASING RUNL P RIH w/ Lower Completion on 4' DP t/ 9,069' MD P/U 150, S/O 136 08:15 08:45 0.50 9,069 9,069 COMPZ CASING CIRC P Circ Tubing Volume - 4 BPM @ 750 Psi 08:45 13:45 5.00 9,069 15,409 COMPZ CASING RUNL P Continue to RIH w/ Lower Completion on 4" Dp t/ 15,409' MD P/U 213, S/O 130 13:45 15:00 1.25 15,409 8,720 COMPZ CASING HOSO P Space Out Liner and Drop Setting Ball - Circ Ball Down 3 BPM @ 650 Psi, Ball On Seat @ 65 Bbls Pumped - Pressure Up to 2100 Psi - Verify Slips Set - Pressure Up t/ 4200 Psi to Shear Ball Seat - Close Rams Pressure Up on Annulus t/ 3500 Psi f/ 5 Minutes - Stand Back 2 Stands ZXP Liner Top @ 8,720' MD 15:00 00:00 9.00 8,720 8,720 COMPZ CASING CIRC T Shut Down Operations Due to Phase III Weather - 1 BPH Static Losses 02/03/2010 Wait on Phase III Weather, Reduced to Phase II @ 0515L - Slip & Cut 90' of Drill Line - POOH w/ ZXP Running Tools on 4" DP - R/U and Run 3 1/2" EUE Upper Completion t/ 8,006' MD per Detail - Repair Top Drive Link Tilt Switch 00:00 05:15 5.25 8,720 8,720 COMPZ CASING TRIP T Continue to Wait on Phase III Weather - Monitor Well w/ TT 1 BPH Static Loss Rate 05:15 06:45 1.50 8,720 8,720 COMPZ RIGMNT SLPC P Slip & Cut 90' Drilling Line - Service Top Drive & Draw Works 06:45 11:15 4.50 8,720 0 COMPZ CASING TRIP P POOH w/ 4" DP and ZXP Running Tools 11:15 12:30 1.25 0 0 COMPZ RPCOM RURD P Pull Drilling Wear Ring and Install Tubing Running Wear Ring - R/U to Run 3 1/2" Tubing Page 27 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 18:45 6.25 0 6,559 COMPZ RPCOM RCST P Run 3 1/2" EUE Upper Completion t/ 6,559' MD as Follows; Baker Bonded Seal Assy & Spacer Tubes, Locator, 10 Jts Tubing, "D" Nipple w/ RHC Installed, 2 Jts Tubing, KBMG GLM w/ DCK -2 Shear Vavle, 52 Jts Tubing, KBMG GLM w/ Dummy Valve, 87 Jts Tubing, KBMG GLM w/ Dummy Vavle, 52 Jts Tubing 18:45 20:15 1.50 6,559 6,559 COMPZ RPCOM SSSV P P/U TRMAXX -5E SSSV - R/U Spooler Unit and Line - M/U Control Line and Test t/ 6,000 Psi f/ 15 Minutes 20:15 22:30 2.25 6,559 8,006 COMPZ RPCOM RCST P Continue to RIH w/ 35 Jts of 3 1/2" EUE Tubing t/ 8,006' MD 22:30 23:30 1.00 8,006 8,006 COMPZ RIGMNI SVRG P Service Rig 23:30 00:00 0.50 8,006 8,006 COMPZ RIGMN1 RGRP T Repair Link Tilt Switch 02/04/2010 Continue Attempt to Repair Top Drive Link Tilt Switch - Rlh w/ 3 1/2" EUE Tubing, XO to 4" DP and Tag Locator on ZXP Packer - Pull Seals Out of Seal Bore then Pump 165 Bbl of Inhibited KCL - M/U 4 1/2" IBT Jts, Space Out Pups and Tubing Hanger - Land Tubing w/ Locator 2' Above ZXP w/ Tail @ 8,766' MD - Set TWC - Test Tubing Hanger t/ 5,000 Psi - R/U and Perform Preliminary Test of Bonded Seal Assy U 1,000 Psi - N/D BOPE and N/U Tree - Test Tree t/ 5,000 Psi -Pull TWC and Drop Ball and Rod Assy - Test Tubing t/ 3,500 Psi - Test IA to 3,500 Psi - Shear Lower GLM Valve and Freeze protect Well w/ 128 Bbls of Diesel - Secure Tree - R/D Manifolds and R/U to UD DP - Shut In Pressure: Tubing 750, IA 0, OA 0 00:00 04:00 4.00 8,006 8,006 COMPZ RPCOM RCST T Continue to Attempt to Repair Top Drive Link Tilt Switch 04:00 05:30 1.50 8,006 8,642 COMPZ RPCOM RCST P Continue to RIH w/ 35 Jts of 3 1/2" EUE Tubing t/ 8,642' MD 05:30 06:45 1.25 8,642 8,605 COMPZ RPCOM HOSO P Crossover to 4" DP - establish circulation - 1 bpm @ 90 psi - RIH w/ Completion equipment - observed pressure increase to 120 psi - shut down pumps - continue to slack off and tagged down with locator sub - mark pipe for space out calculations - stand back 1 stand of drill pipe . 06:45 07:00 0.25 8,605 8,605 COMPZ RPCOM SFTY P PJSM on Pumping Inhibited KCL 07:00 08:30 1.50 8,605 8,605 COMPZ RPCOM CRIH P RU and pumped 165 bbls of 9.2 ppg corrosion inhibited brine 4.2 bpm @ 470 psi - blow down Top drive 08:30 10:00 1.50 8,605 8,730 COMPZ RPCOM RCST P Stand back 1 stand of DP - change elevators and MU two space out pups and two full joints of 4 1/2" tubing - MU wear bushing retrieving tool and retrieve wear bushing 10:00 11:15 1.25 8,730 8,766 COMPZ RPCOM THGR P MU FMC tubing hanger and LJa - strip SSSV control line thru and test SSSV connector to 5000 psi - Land hanger into wellhead and RILDS - Tail @ 8766' 11:15 12:00 0.75 8,766 8,766 COMPZ RPCOM THGR P Change Out Landing Jts, Set TWC and Test Tubing Hanger Seals t/ 5,000 Psi f/ 5 Minutes Page 28 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 8,766 8,766 COMPZ RPCOM PRTS P R/U and Perform Prelimiary Test of Seal Assemblies t/ 1,000 Psi f/ 5 Minutes 12:30 14:00 1.50 8,766 0 COMPZ WHDBO NUND P N/D Riser and BOPE Stack 14:00 16:00 2.00 0 0 COMPZ WHDBO NUND P N/U Tree and Test t/ 5,000 Psi f/ 5 Minutes 16:00 17:30 1.50 0 0 COMPZ DRILL RURD P R/U Doyon Lubricator and Drop the Ball & Rod - R/U Hardlines and Manifold 17:30 19:45 2.25 0 0 COMPZ DRILL PRTS P With Dowell Unit: Test Surface Lines t/ 4,000 Psi - Test Tubing t/ 3500 Psi f/ 30 Minutes, Pressure Bled to 3471 - Bleed Tubing Pressure t/ 2,000 Psi Accross Mainfold Into Annulus - Test Annulust t/ 3537 Psi f/ 30 Minutes, Annular Pressure Bled t/ 3503 Psi - Bled Tubing Pressure & Observed Shear Valve Shear at 2500 Psi Differential (1,000 Psi on Tubing) 19:45 21:00 1.25 0 0 COMPZ DRILL FRZP P Freeze Protect Well by Pumping 128 bbl Diesel 2 BPM Through Sheared GLM w/ Dowell Cement Unit 21:00 22:45 1.75 0 0 COMPZ DRILL RURD P Flush Lines w/ Water Then Blow Down - R/D Hard Lines and Manifold - Set BPV and Secure the Well Head • - Initial SITP 750, IA 0, OA 0 22:45 00:00 1.25 0 0 COMPZ DRILL RURD P Clean & Clear the Rig Floor - R/U to UD 4" DP f/ the Derrick 02/05/2010 UD 4" DP f/ the Derrick - Change Saver Sub - Clean Pits - Release Rig @ 2300 00:00 12:00 12.00 0 0 COMPZ DRILL PULD P UD 4" DP f/ the Derrick 12:00 22:00 10.00 0 0 COMPZ DRILL PULD P Continue to UD 4" DP f/ the Derrick and Clean Pits 22:00 23:00 1.00 0 0 COMPZ DRILL RURD P Change Saver Sub t/ 4 1/2" IF - Clean /Clear Rig Floor - Bring Sperry Subs to Rig Floor Rig Released @ 2300 Hrs Page 29 of 29 • CD3 -122 Post Rig Well Events DATE SUMMARY 2/12/10 PULLED SOV FROM 8326' RKB, REPLACED W/ PETREDAT SIDE POCKET MEMORY GAUGE. PULLED BALL & ROD FROM RHC PLUG BODY. PULLED RHC PLUG BODY ON CR LOCK FROM D NIPPLE @ 8406' RKB. SET FRAC SLEEVE IN TRDP @ 2198' RKB. COMPLETE. 2/24/10 PREPARED TO PUMP MULTI -STAGE FRAC. DUE TO ONE OF THE FRAC PUMPS NOT STARTING AND A HYDRAULIC PUMP FAILURE IN THE PCM, JOB WAS POSTPONED FOR A DAY WAITING ON REPLACEMENT PUMP AND PARTS. 2/25/10 PUMPED A TOTAL OF 1,059,078 LBS OF 16/30 COLORADO WHITESAND PLACED BEHIND PIPE. FRAC PUMPED TO 107% DESIGN. ISIP = 2101 PSI, 15 MIN WHP = 1690 PSI. FREEZE PROTECTED WELL WITH 35 BBL OF DIESEL. 2/26/10 STAND BY FOR FRAC EQUIPMENT TO BE RIGGED DOWN. JOB POSTPONED UNTILL A.M 2/27/10 PULLED FRAC SLEEVE @ 2198' RKB, DROPPED 2.25" BALL DOWN TUBING LRS PUMPED 74.7 BBLS SHEARD SLEEVE @ 9802' RKB, PULLED 1" PETREDAT SIDE POCKET GAUGE @ 8326' RKB, SET 1" OV W/ (1/4" PORT) @ SAME, PULLED 1" DMY VLV © 6650' RKB, SET 1" GLV (3/16" PORT / TRO= 1677), PULLED 1" DMY VALVE @ 3874' RKB, SET 1" DMY VALVE @ SAME, SET FRAC SLEEVE IN TRDP @ 2198' RKB. COMPLETE 1 4110 WELL LOG TRANSMITTAL To: State of Alaska February 9, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3 -122 AK -MW- 0006991483 CD3 -122 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20609 -00 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20609 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50- 103- 20609 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office:. 907 - 273 -3536 Fax: 907 - 273 -3535 Bryan.Burinda @halliburton.com 0 Date: Signed: low- w • • „_ 4 \ ° �` tl SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 , FAX (907) 276 -7542 Mr. Rami Jasser Wells Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, Fiord Oil Pool, CD3 -122 Sundry Number: 310 -034 Dear Mr. Jasser: 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ) Daniel T. Seamount, Jr. Chair DATED this/ day of February, 2010. • Encl. ,- c _ l 5 • fil U ' "ALAS•IL AND GAS CONSERVATION ERVATI � ON COMMIS& RECEIVED \ V , k %` 1 APPLICATION FOR SUNDRY APPROVALS FEB 0 9 2010 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool J`-' Repair well r Alastagii&istakesipConrisiign Suspend r Rug Perforations (' Perforate r Pull Tubing r AffettAtes ion r Operational Shutdow n r Re -enter Susp. Well r Stimulate p' • Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 . Exploratory r 209 -153 - 3. Address: Stratgraphic r Service -- 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20609 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No (r+ CD3 - 122 • 9. Property Designation: 10. Field /Pool(s): ADL 372105 • Colville River Field / Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15409' 7029' Casing Length Size MD ND Burst Collapse Conductor 114' 16" 114' 114' Surface 2685' 9 -5/8" 2685' 2485' Intermediate 9130' 7" 9130' 6958' Liner 6689' 2.375" 15409' 7029' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" L - 80 8766' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) Baker ZXP © 8720' MD / 6929' ND Camco SSSV 2198' MD / 2097' ND 12. Attachments: Description Summary of Proposal i 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/17/2010 Oil T✓ • Gas r WDSPL r Plugged r 16. Verbal Approval: Date: WINJ r GINJ J° 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: Rami Jasser © 263 -4180 Printed Name Rami Jasser Title: Completions Engineer / Signature / / fr., Phone: 263 -4180 Date 2 /g /.2o, p Commission Use Only Sundry N tub Conditions of approval: Notify Commission so that a representative may witness /' 0 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /Q . L�/b y APPROVED BY e/6 Approv_• . : ° 4 i / C OMMISSIONER THE COMMISSION Date: 'orm 10 -403 Reviidl1 / -� �f `; — ORI J I N [� L 2• /G • • /V Submit in Duplicate I • Overview: CD3 -122: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Nechelik sand. This will • increase the wells production rate. A coil cleanout will only be performed should it be necessary post -frac. Procedure: 1. MIRU at least twenty -three clean insulated frac tanks. Load tanks with Seawater from CD3 injection manifold. (approximately 10500 bbls are required for the treatment) 2. Rig up Schlumberger pumping services equipment and stab the Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger) 3. Pressure test surface lines to 9000 psi 4. Pump the 300 bbl Breakdown with WF125 fluid. Bring pumps up to maximum rate ASAP. SD and obtain ISIP & Pc. 5. Pump 300 bbl DataFRAC to determine fluid leakoff rates 6. Adjust pad volume as necessary based on DataFRAC results a. Pump Schlumberger's schedule at 20 BPM with a maximum pressure of 7000 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment using Little Red's pump truck. b. 5 Stages of 2,4,6, 8 PPA containing: • 1900 bbls YF125ST slurry • 995 M lbs. —16130 white sand • 5 Frac balls will be dropped between stages (1.75 ", 1,875 ", 2.0 ", 2.125" and 2.25 ") • Flush with 50 bbls YF125ST; 50 bbls WF125, and 44 bbls diesel (94 bbls to first frac port) Alpine - CD3 -122 Nechelik Producer ' Ulmer Completion M12 up Lower Completion MD TVD 1) Tubing Hanger 32' 32' 16) Baker 5" X 7" Flex Lock Hanger and ZXP Liner Top Packer 8720' 6929' ' : 1 6" Conductor to 114' 2) 4 -1/2 ", 12.6 # /ft, IBT -Mod Tubing (2 jts) w/ Sealbore Extension 3) Crossover 4 -1/2" x 3 -1 /2" 17) XO 5" BTC X 3.5" SLHT 4) 3 -1/2" Camco TRMAXX -5E SSSV (2.812" ID) 2198' 2097' 18) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 5) 3-1/2", 9.3 # /ft, EUE -Mod Tubing 19) 3 -1/2", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 9786' 6973' 6) 3 -1/2" Camco KBMG -GEM w/ DV 3875' 3422' Reslink 316E wire wrap to hold Resman Tracer 20) 3-%" SLHT Baker Ball Actuated Sleeve (2.125" Seat ID) (2.250" Ball) 9801' 6974' 11 7 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubin g 21) 3-1/2", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 9809' 6974' 9 -5/8" 36 ppf J - BTC 8) 3 -1/2" Camco KBMG -GLM w/ DV 6650' 5611' Reslink 316E wire wrap to hold Resman Tracer 9) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 2 2 3 -1/2 ", 9.3 # /ft, SLHT Tubing Surface Casing ) g at 2,685' MD / 2,485' TVD 10) 3 -1/2" Camco KBMG GLM w/ DCK2 Shear 8326' 6813' 23) 15' Swell Packer (3-%" SLHT) OD 5'/." w/ 5' sealing element 10424' 6986' Cemented to Surface Set @2500psi 24) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 11) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing (2 Jts) 25) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 10817' 6993' 12) 3 -1/2 ", "D" Nipple w/ RHC Plug 8406' 6844' Reslink 316L wire wrap to hold Resman Tracer at 67° inc (2.75" ID) 26) 3-W SLHT Baker Ball Actuated Sleeve (2.000" Seat ID) (2.125" Ball) 10833' 6994' 3 - 1/2" 9.3 ppf L - EUE 13) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 27) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 10840' 6994' 14) 3-1/2", 9.3 # /ft, EUE -Mod pup joint Reslink 316L wire wrap to hold Resman Tracer Tubing 15) Seal Assembly (xx' of seals) 8755' 6934' 28) 3 -1/2 ", 9.2 # /ft, SLHT Tubing 1 and WLEG stung in X' (TBD) below 29) 15' Swell Packer (3 -W SLHT) OD 5-%" w/ 5' sealing element 11295' 7003' GL I Liner Hanger 30) 3 -1/2 ", 9.3 # /ft, SLHT Tubing TOC = +/ - 4,172' MD / 31) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 11723' 7011' Reslink 316L wire wrap to hold Resman Tracer +/ - 3,656' TVD 32) 3 -' /" SLHT Baker Ball Actuated Sleeve (1.875" Seat ID) (2.000" Ball) 11738' 7012' Qannik Interval 33) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 11746' 7012' To +/ 4,672 MD / 4,049' TVD Reslink 316E wire wrap to hold Resman Tracer Top 34) 3 -1/2 ", 9.3 # /ft, SLHT Tubing Base +/ - 4,697' MD / 4,069' TVD 35) 15' Swell Packer (3-%" SLHT) OD 5-%" w/ 5' sealing element 12200' 7020' Stage Collar 36) 3 -1/2 ", 9.3 # /ft, SLHT Tubing y g g 37) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 12626' 7029' / � +1- 5,172' MD / 4,446' TVD Reslink 316L wire wrap to hold Resman Tracer 38) 3 -%" SLHT Baker Ball Actuated Sleeve (1.750" Seat ID) (1.875" Ball) 12641' 7029' 39) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 12649' 7029' Reslink 316L wire wrap to hold Resman Tracer 40) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 41) 15' Swell Packer (3-%" SLHT) OD 5-%" w/ 5' sealing element 13109' 7038' 42) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 43) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 13505' 7046' Reslink 316L wire wrap to hold Resman Tracer GL 44) 3-%" SLHT Baker Ball Actuated Sleeve (1.625" Seat ID) (1.750" Ball) 13520' 7046' 45) 3-1/2", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 13528' 7046' Reslink 316L wire wrap to hold Resman Tracer 46) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 47) 15' Swell Packer (3-W SLHT) OD 5-%" w/ 5' sealing element 13863' 7053' 48) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 49) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 14573' 7066' Reslink 316L wire wrap to hold Resman Tracer 50) 3 - %" SLHT Baker Ball Actuated Sleeve (1.500" Seat ID) (1.625" Ball) 14588' 7067' 51) 3 -1/2 ", 9.3 # /ft, SLHT Tubing 18' blank pup joint w/ 12' of 14597' 7067' Reslink 316L wire wrap to hold Resman Tracer 52) 3-1/2", 9.3 # /ft, SLHT Tubing 7" 26 ppf L - BTC - 53) 3 -' %" SLHT Float Shoe 15398' 7073' Production Casing 15399' 7073' TOC @ +/ 7,796' at 9,130' = 6,958' ND @ +/- 86.3° 3 -1/2" 9.3 ppf L -80 SLHT TD 6 - 1/8" hole MD / 6,501' TVD Liner 15,409' MD / 7029' TVD 0 23 29 35 41 0 53 Top of KupanJk 8,296' MD / 6,792 r 20 26 32 38 44 50 TVD 44=1.1113) a. � .• • 4. 1 Top of Nechelik `iii:'>::: _ 8,789' MD / 6,939 �`''''- i__:. AD ® 25 27 ®® 37 39 4 45 = 49 51 III TVD s' ' >' €iii • a ji:.. • • CD3-122 - D 0 Q\- k Information csi\Z r • • CD3 -122 Surface Casing Well: D3 - 122 9625 . 0 .:4 . L -8 0, 87C-n7 q#sincI Date: 1115/2010 ConocoPh111p l s Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 it :::::::::::::::....::::::::.:.::::::::::::::: 1pptrri.p .1az.f a g Doyon 19 RKB to landing Ring 36.10 11111111,11 II; FMC Gen V 9 -5/8" Fluted Hanger (15 -114" OD) (pxp pup 2.43') 2.47 36.10 Jts 3 to 69 67 Jts 9 -5/8" 40 ppf L -80 BTC -m casing 2565.24 38.57 Halliburton 9 -5/8" "Sure Sean!" Float collar (10.67" OD) 1.24 2603.81 Jts 1 to 2 2 Jts 9 - 5/8" 40 ppf L - BTC - casing 77.80 2605.05 Rays Oil Tools 9 - 5/8" "Silver Bullet" Float Shoe (10.67" OD) 2.20 2682.85 2685.05 2685.05 2685.05 12 -1/4" TD @ 2695' MD / 2492.6' TVD 2685.05 9-5/8" Casing Shoe @ 2685.05' MD / 2484.78' TVD 2685.05 2685.05 2685.05 75 Joints in Pipe Shed - Run 69 / Last 6 jts. out 2685.05 2685.05 One bowspring on stop 10' above shoe and on collar of jt #1. 2685.05 One bowspring on stop 10' below collar of jt #2. 2685.05 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 -67 2685.05 Total 41 Bowsprings - Two Stop Collars 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685:05 2685.05 2685.05 Remarks: Average MU torque = 9500 ft lbs Up Wt 175 K Drifted pipe w/ plastic rabbit 8.76" OD Dn Wt 145 K Used Run N Seal dope. Block Wt 74 K Supervisors: David Burley / Granville Rizek Via' Cement Detail Report :4 is : > 'i, :R CD3 -122 Pli�l i�f�l u p, 4 ConocoPhillips illl ° I String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Cement Details ,, Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/15/2010 07:45 1/15/2010 10:15 CD3 -122 Comment Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked, floats OK, CIP @ 1015 hrs. Had full returns throughout job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbls of displacement. Cement Stages - Stage #1 ' Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 2,685.0 Yes 58.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 4 5 490.0 1,050.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 8 3/4 Comment Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Cement Fluids & Additives == Fluid °_= Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water 35.0 Yield (ft' /sack) Mix H2O Ratio (gaUsa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label .Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 50.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid - = _ - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) ArcticSet Lite 36.1 360 293.0 Yield (ffl/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.57 21.23 10.70 Additives Additive Type Concentration Conc Unit label S001 Accelarator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 antifoam 0.6 %BWOC Additive Type Concentration Conc Unit label D079 extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 extender 50.0 %BWOC Additive Type Concentration Conc Unit label D044 Freeze suppressant 9.0 %BWOW Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Page 1/2 Report Printed: 2/8/2010 1 • • �lli t Cement Detail Report 1Ipld1 1 1ih' � ll / CD3 -122 P I u ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 , Cement Fiuids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surf Tail 2,185.0 2,685.0 140 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC I l i Page 2/2 Report Printed: 2/8 /2010 • Security Level: AK Development ' Daily Drilling Report als ail CD3 -122 ConocoPhillips Report Number: 5 Rig: DOYON 19 Report Date: 1/14/2010 AFE Type NetwoddlD # Totat AFE +Sup 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -122 Development FIORD NECHELIK 2.02 5.0 573.00 2,122.0 2,695.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 19,210.45 42, 500.61 194,201.45 1,166,937.61 Actual Start Date Original Spud Date AFE Our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 26.30 2.60 2/5/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Conductor, 114.0ftKB Ops and Depth @ Morning Report 24hr Forecast Circ & recip 9 -5/8" csg prior to cement @ 2685'. Continue to run 9 -5/8" casing to 2685', circulate, cement, Rig down riser, Nipple up BOPE, test BOP equipment. Last 24hr Summary Continue to drill 12 -1/4" surface hole f/ 2122' to 2695' (2492' TVD). Circulate and condition mud and hole, Backream out from 2695' to 908', blow down the top drive, monitor well- static, trip in f/ 908' to 2695', circulate bottom's up, Trip out to 169', lay down BHA #1. Clear floor. Rig up to run 9 -5/8" surface casing. Pre job safety meeting. Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. General Remarks Weather Head Count No Accidents / No Spills -37 °, WC -68 °, Wind SW @ 17 Mph, 5 mile 49.0 vis supeevisor " " Title - Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log Start End Our -- Time Depth Start Depth End Time Time (hrs) Phase= Op Code Activity Code P T X - Trbl Code Trbl Class. (ftKB) (ftKB) operation 00:00 07:45 7.75 SURFAC DRILL DDRL P 2,122.0 2,695.0 Drill 12 -1/4" surface hole f/ 2120' to 26952'. Drill w/ 10 to 25k weight on bit. Rotate 80 rpm w/ 7k ft lbs of torque on bottom, 6k off bottom . Pumping 603 gpm w/ 1310 -1750 psi. Actual driling time 6.28 hrs, 5.02 rotating and 1.26 hrs sliding. PU wt 140k, SO wt 140k, Rot wt 141k. 07:45 09:00 1.25 SURFAC DRILL CIRC P 2,695.0 2,695.0 Circulate and condition mud and hole. Pumping 650 gpm w/ 1850 psi. Rotate 80 rpm w/ 6500 ft lbs of torque. Floc check- static. 09:00 12:45 3.75 SURFAC DRILL REAM P 2,695.0 908.0 Backream out of the hole from 2695' to 908' (top of HWDP). While backreaming from 2695' to 1500': Pumping 600 gpm w/ 1550 psi. Rotate 80 rpm w/ 6500 ft lbs of torque. While backreaming from 1500' to 908': Pumping 500 gpm w/ 1140 to 1100 psi. Rotate 80 rpm w/ 5000 ft lbs of torque. 12:45 13:00 0.25 SURFAC DRILL OTHR P 908.0 908.0 Blow down the top drive. 13:00 13:15 0.25 SURFAC DRILL OWFF P 908.0 908.0 Flow check- static. Note: Went off hi- line at 1252 hrs, then back on highline at 1357 hrs 1/14/2010. Working to rearrange transformer f/ continued simops on CD3 pad. 13:15 14:15 1.00 SURFAC DRILL TRIP P 908.0 2,695.0 Trip in the hole on elevators from 908' to 2695'. Hole in good condition. Latest BOP Test Data Date "' Comment Page 1/3 Report Printed: 2/8/2010 _g • •ecurity Level: AK Development i ■,,, Daily Drilling Report P CD3 -122 COnaCOf'Fs - i Report Number: 5 Rig: DOYON 19 Report Date: 1/14/2010 ,Time -Log - Start. End Our Time `;Depth Start Depth End ` Time -- Time (firs) Phase - -Op Code Activity Code P -T -X Trbi Code " Trbl Class. (ftKB) -OW3) - Operation 14:15 15:30 1.25 SURFAC DRILL CIRC P 2,695.0 2,695.0 Circulate bottom's up or hole clean. Pumping 691 to 666 gpm w/ 1700 to 1900 psi. Rotate 80 rpm w/ 6500 ft lbs of torque. 15:30 17:30 2.00 SURFAC DRILL TRIP P 2,695.0 908.0 Pull out of the hole on elevators from 2695' to 908' (top of 5" HWDP). 17:30 18:00 0.50 SURFAC DRILL TRIP P 908.0 169.0 Stand back 5" HWDP f/ 908 to 169'. 18:00 19:30 1.50 SURFAC DRILL PULD P 169.0 0.0 Lay down BHA #1. 19:30 20:15 0.75 SURFAC DRILL PULD P 0.0 0.0 Clean and clear rig floor. 20:15 21:45 1.50 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 -5/8" 40 ppf L -80 BTC -m surface casing. 21:45 22:15 0.50 SURFAC CASING SFTY P 0.0 0.0 Prre job safety meeting on running casing. 22:15 23:00 0.75 SURFAC CASING RNCS P 0.0 121.0 Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. 23:00 23:45 0.75 SURFAC CASING CIRC T Non -rig Other 121.0 121.0 Attempt to fill pipe and check floats using Surface Eqp Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. 23:45 00:00 0.25 SURFAC CASING CIRC P 121.0 121.0 Fill three joints of casing, circulate surface to surface. Float equipment works fine. .mutt Check Data _ ° - : : : : - - r - YP Cale Get (10s) _ _ Gel (10m) Get (30m) 1111.1P Filt Density Temp • Solids. Corr. Type = Depth (ftt0 } Dens (iWgal) Vis (slat) .,'PV Cab (cp) (lbft100ft) (Ibfl100fP):3- (lbf /100ft9 (Ibf /100 t) MST (lb/bbl} -- ttn fl30min), pH _ (°F) (%) Spud Mud 2,695.0 10.00 250 23.0 42.0 38.0 79.0 88.000 27.5 9.0 9.5 Spud Mud 2,423.0 9.80 300 6.0 62.0 53.0 59.0 0.000 27.5 8.8 8.0 injection Fluid =Fluicd Source From Lease (bbl) Destination Vendor Manifest Number = __ _ - Note _ Diesel 10.0 CD3 -305 MI Swaco injectivity test Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329658 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329660 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329657 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329656 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329655 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329653 Water Based Mud CD3 -122 280.0 CD1 -19 ASRC 329654 Water Based Mud CD3 -122 82.0 CD1 -19 ASRC 329659 Drill Strings: BHA No. 1 - 8" ABI Mtr4 /5 5:31 Bit Run No. "'1 - 12 1/4in, Hughes Christensen , MXL -1X, 5170925 ,_ -- Depth In (ftKB) Depth Out (ftKB) TFA (Intl Noz)'(in') Nozzles (/32 ") IADC Bit Dull String Wt (1000Ibf) 114.0 2,695.0 1- 3- WT- A- E- 2 -NO -TD Drill String Components .fts - -,- '- Item Description _ - =_ = _ -- OD (in)=:- ID (in) Top Conn Sz (in) - - :Top Thread Cum Len (ft) 1 Motor with Stabilizer 8 5.000 6 5/8 H 90 1.10 1 Non -Mag Float Sub 8 2.750 6 5/8 H 90 1.10 1 Stabilizer (Non Mag) 8 3.000 6 5/8 H 90 1.10 1 MWD - HCIM 8 1.920 6 5/8 H 90 1.10 1 MWD - DM 8 1.920 6 5/8 H 90 1.10 1 MWD - TM 8 1.920 6 5/8 H 90 1.10 1 UBHO (Non -Mag) 8 3.000 6 5/8 H 90 1.10 Page 2/3 Report Printed: 2/8 /2010 • Security Level: AK Development Daily Drilling Report CD3 -122 cc , e rhttl , Report Number: 5 Rig: DOYON 19 Report Date: 1/14/2010 Drill String Components ate , ; Item Desc - -_ = OD (in) ID (in) Top Conn Sz(in) Top Thread =Cum Len (ft) 1 Drill Collar 8 2.813 6 5/8 H 90 1.10 1 Drill Collar 8 2.813 6 5/8 H 90 1.10 1 Drilling Jars - Hydraulic 8 2.750 4 1/2 IF 1.10 24 HWDP 5 3.000 6 5/8 H 90 1.10 res Welibo Wellbore Name Wellbore API /UWI CD3 -122 501032060900 Section - .,, Size (in) - _= Act Top (ftKR) Act Btm (ftKB) Start Date` >_ = End Date COND1 24 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Survey Data -- MD- (ftKS) Ind ( Azm ( °) TVD (ftKB) VS - NS (ft) EW (ft) DLS ( °710Qtt) 2,189.38 33.17 286.94 2,089.73 - 462.74 252.73 - 433.51 2.27 2,283.29 35.05 286.63 2,167.48 - 505.22 267.94 - 483.93 2.01 2,379.65 37.79 285.97 2,245.01 - 551.08 283.98 - 538.83 2.87 2,474.73 38.60 286.09 2,319.74 - 598.05 300.22 - 595.34 0.86 2,570.06 38.21 285.12 2,394.44 - 645.10 316.15 - 652.37 0.75 2,649.05 38.23 284.82 2,456.50 - 683.59 328.77 - 699.59 0.24 Page 3/3 Report Printed: 2/8 /2010 • �y • •ecurity Level: AK Development Daily Drilling Report CD3 -122 Report Number: 6 ConocoPhitliips Rig: DOYON 19 Report Date: 1/15/2010 AFE Type k iV, Network/ID # Total AFE +Sup 10271110 11,115,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 122 Development FIORD NECHELIK 3.02 6.0 0.00 2,695.0 2,695.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,668.51 52,169.12 444,152.51 1,611,090.12 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 27.30 1.60 2/6/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,685.1ftKB Ops and Depth @ Morning Report 24hr Forecast MU BHA #2, depth approx 733'. Pick up/ Make up/ Stand back 5" drill pipe, MU BHA #2, single in w/ 5" f/ pipe shed, test csg to 3500 psi, drill shoe track and 20' new, perform FIT to 18 ppg, drill ahead 8 -3/4" intermediate Last 24hr Summary Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to 1620' circulate bottom's up, continue to run casing to land on hanger w/ shoe @ 2685'. PJSM, rig down casing equipment, rig up Dowell cement head and lines, circulate and condition mud and hole f/ cement, Dowell cement 9 -5/8" casing, rig displace w/ 9.9 ppg mud, bump plug w/ 58 bbls of good 10.7 ppg cement to surface. Rig down cementing and casing running tools.Lay down landing joint. PJSM, nipple down, nipple up wellhead, test metal to metal seal to 1000 psi f/ 10 minutes, PJSM, nipple up BOPE, rig up to test, test BOPE w/ 5" test joint. Witness of test waived by AOGCC inspector Jeff Jones. Pull test joint and test plug, install FMC wear bushing, rig up drilling bales and 5" drill pipe elevators, PJSM, pick up, make up/ stand back 5" drill pipe in the derrick. General Remarks Weather Head Count No Accidents / No Spills -31°, WC -53 °, Wind SW @ 17 Mph, 4 mile 49.0 vis Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log Start End Dur Time Depth Start Depth End Time Time - (tars)' phase Gip Code - _ Activity Code =_P Trbl Code=_ Trbr,Class. MO) ( } Operation 00:00 02:45 2.75 SURFAC CASING RNCS P 121.0 1,620.0 Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to joint # 42 (1620'). Note: Ran centralizers one per joint up to jt # 13, then every other joint. 02:45 03:15 0.50 SURFAC CASING CIRC P 1,620.0 1,620.0 Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. 03:15 04:45 1.50 SURFAC CASING RNCS P 1,620.0 2,685.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Continue to install bow spring centralizers over collars to joint # 67. 04:45 05:00 0.25 SURFAC CASING SFTY P 2,685.0 2,685.0 Pre job safety meeting on rigging down casing tools and rigging up to cement. 05:00 05:15 0.25 SURFAC CASING RURD P 2,685.0 2,685.0 Rig down casing running equip (Frank's fillup tool) 05:15 05:30 0.25 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig up Dowell cementing head, make up 2" cementing line. 05:30 07:15 1.75 SURFAC CEMENT CIRC P 2,685.0 2,685.0 Circulate and condition mud and hole f/ cement. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. FCP= 310 psi PUW 163K SOW 149K 640 bbls pumped Latest BOP Test Data .,Date == , 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/4 Report Printed: 2/8 /2010 • Security Level: AK Development 16 M ,, Daily Drilling Report qj CD3 -122 Ccxx�e+oi�htuiPs;',Illi Report Number: 6 Rig: DOYON 19 Report Date: 1/15/2010 Time Log Start End Our Time Depth Start - Depth End Time Time (hrs) Phase Op Code - - - Activity Code = P-T-X Trbl Code; Trbi Class. (ftKB) (ftKB) = = Operation 07:15 07:45 0.50 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. 07:45 09:45 2.00 SURFAC CEMENT PUCM P 2,685.0 2,685.0 Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. 09:45 10:15 0.50 SURFAC CEMENT DISP P 2,685.0 2,685.0 Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbls of displacement. 10:15 10:30 0.25 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on rigging down cement equipment. 10:30 11:15 0.75 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig down cementing equipment. 11:15 11:30 0.25 SURFAC DRILL PULD P 2,685.0 0.0 Back out FMC landing joint w/ 10.75 4SAM2 -Left hand threads. Lay down the landing joint. 11:30 11:45 0.25 SURFAC DRILL PULD P 0.0 0.0 Lay down the mouse hole. Clean and clear rig floor of tools. 11:45 12:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippling down surface riser. 12:00 13:15 1.25 SURFAC WHDBOP NUND P 0.0 0.0 Nipple down surface riser. 13:15 14:00 0.75 SURFAC WHDBOP NUND P 0.0 0.0 Remove FMC starting head. Install FMC wellhead. 14:00 14:15 0.25 SURFAC WHDBOP DHEQ P 0.0 0.0 Install FMC wellhead. Test FMC metal to metal seal to 1000 psi, hold for 10 minutes. Good test. 14:15 14:30 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippling up BOP equipment. 14:30 16:45 2.25 SURFAC WHDBOP NUND P 0.0 0.0 Nipple up 13 -5/8" 5m BOP stack. 16:45 17:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on testing BOPE. III Page 2/4 Report Printed: 2/8 /2010 •ecurity Level: AK Development • a Daily Drilling Report 1111 , F 1 &� - CD3 -122 CcetsPhiillps Report Number: 6 Rig: DOYON 19 Report Date: 1/15/2010 Time Log Start End Dur Time Depth Start Depth End Time Time-- _ (hr* Phase Op Code `- Activity Code P T X Trb1 Code Trbl Class. (ftKB)' (ftlfB) ,, Operation 17:00 18:00 1.00 SURFAC WHDBOP BOPE P 0.0 0.0 Rig up to test BOPE. Set FMC lower test plug. Fill stack and choke manifold with water. 18:00 21:30 3.50 SURFAC WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1550 psi after operating. Recovery time test of 33 seconds for 200 psi build up and 2 minutes 55 seconds for full charge. Nitrogen bottles average 1650 psi. 21:30 21:45 0.25 SURFAC WHDBOP OTHR P 0.0 0.0 Pull test joint and test plug, blow down kill and choke lines. 21:45 22:00 0.25 SURFAC WHDBOP OTHR P 0.0 0.0 Install FMC long wear bushing. 22:00 22:15 0.25 SURFAC DRILL RURD P 0.0 0.0 Pickup short drilling bales, attach to the top drive. Install 5" drill pipe elevators. 22:15 22:30 0.25 SURFAC DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up and standing back 5" drillIpipe. 22:30 00:00 1.50 SURFAC DRILL PULD P 0.0 0.0 Pickup/ makeup/ standback in the derrick 5" drill pipe. 8 stands picked up. Mud Check - YP Cato G et (10s) _ -= Gel (10m) Get (30m) FrfliP -Alt Density Temp Solids, Corr.?, :TypeF Depth ftKB) _ dens (tb/gal) = Vis- (slat; PV Cale (cp) (Ibf11NT) - 7; iflbf/100fPV (Ibftl00ft ") llbf /100fP) MBT (lbJbbt) -_= ff, Omtn) pFC ",'' ( (%)biligt Spud Mud 2,685.0 9.60 61 8.0 15.0 4.0 5.0 5.000 30.0 9.0 9.0 injection Fluid °. FEUid - _ - Sar ee__ _ From Lease (bbl) Destination Vendor = Manifest - : Number = Note Diesel 10.0 CD3 -305 Water 40.0 CD3 -305 Water Based Mud CD3 -122 1335.0 CD3 -305 Water Based Mud CD3 -122 311.0 CD3 -305 cement contaminated mud Water Based Mud CD3 -122 58.0 CD3 -305 cement contaminated mud Welibores Wellbore Name Wellbore API /UWI CD3 -122 501032060900 Saction - Size (in) Act Top (ftKB) _- _ - Act atm (ftKB) ; Start Date End Date CONDI 24 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Page 3/4 Report Printed: 2/8/2010 •ecurity Level: AK Development Daily Drilling Report II lul CD3 -122 �''I '0' / Report Number: 6 �t(sPhiaips II ���» Rig: DOYON 19 Report Date: 1/15/2010 Casing Strings String OD String Wt Casing Description _ Run Date (in) ` -- _(Ibs/ft) String Grade - Set Depth (ftKB) Comment Surface 1/15/2010 9 5/8 40.00 L - 80 2,685.1 Make up Ray Oil tool 9 - 5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to joint # 42 (1620'). Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Pre job safety meeting on rigging down casing tools and rigging up to cement. Rig down casing running equip (Frank's fillup tool/ slips). Rig up Dowell cementing head, Make up 2" cementing line. Circulate and condition mud and hole f/ cement, final mud properties: MW 9.9 ppg, vis 60 to 70. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. Circulated 685 bbls prior to cementing. Note: Centralizers: 10' above shoe over a stop, one on collar of jt #1, 10' below float collar on jt #2, then one per joint up to jt # 13, then every other joint to jt # 67 for a total of 41 bow centralizers and 2 stop rings. Cement - - Surface Casing Cement - Started @ 1/15/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 122 Surface, 2,685.1ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.0 2,685.0 4 490.0 Glass Amount (sacks},_-- = = = =V (bbl} 'Density (IbIgal) Yield (ft'Isack) - Est Top, (ftKB) Est Btm (ftKB) Viscosified Water 35.0 8.40 MudPush II 50.0 10.50 ArcticSet Lite 360 293.0 10.70 4.57 36.1 Alpine Surf Tail 140 50.0 15.80 1.17 2,185.0 2,685.0 Page 4/4 Report Printed: 2/8 /2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-122 Rig: Doyen 19 Date: 1/16/2010 Volume In •ut Volume/Stroke Pum • Rate: Drilling Supervisor: D. Burley/ G. Rizek Pump used: #2 Mud Pump V Strokes 0.1000 Bbls/Strk :'H.74:10 Strk/min Type of Test: Casing Shoe Test LOT/FIT NI Pumping down annulus and DP. V - , - Casing Test Pressure Integrity Test Hole Size: 8 ■ Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 33.6IFt 2685.01Ft-MD1 2484.OIFt 2715.OIFt I 2508.01Ft-TVD _ Strks psi Min 1 psi Strks psi Min psi Casing Size and Description: 9 40#/Ft L BTC V 0 70 0 3630 0 10 0.00 1060 Casing Test Pressure IntearitvTest 2 180 1 3630 1 40 0.25 870 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 4 320 2 3630 2 90 0.50 750 Mud 10 min Gel: 40.0 Lb/100 Ft2 Mud 10 min Gel: 40.0 Lb/100 Ft2 6 540 3 3630 3 180 1.00 700 Test Pressure: 3500.0 psi Rotating Weight: WNW* Lbs 8 760 4 3620 4 280 1.50 680 Rotating Weight: #44/4144 Lbs Blocks/Top Drive Weight: 75000.0 Lbs 10 910 5 3620 5 400 2.00 660 Blocks/Top Drive Weight: 75000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1070 6 3620 6 500 2.50 660 Estimates for Test: 2.4 bbls Estimates for Test: 1085 psi 0.7 bbls 14 1280 7 3620 7 590 3.00 65 v 'll' 16 1470 8 3620 8 670 3.50 640 EMW = Leak-off Pressure + Mud Weight = 870 PIT 15 Second 18 1660 9 3610 9 740 4.00 640 0.052 x TVD 0.052 x 2484 + 9.6 Shut-in Pressure, psi 20 1860 10 3610 10 820 4.50 630 EMW at 2685 Ft-MD (2484 Ft-TVD) = 16.3 ppg 870 22 2090 15 3610 11 870 5.00 630 4000 Lost 30 psi during test, held 24 2330 20 3600 12 900 5.50 620 L 99.2% of test pressure. 26 2590 25 3600 13 940 6.00 620 ,. 0„.„., withhao,,...........-, .. 3500 IIIIMM■■■1111■■ 28 2830 30 3600 14 990 6.50 610 ■■■■■••■ 30 3100 15 1030 7.00 600 ......■■■■■ 3000 ' 1111•1111111111■■■■11•IM 32 3370 16 1070 7.50 600 „ ■■•...1■■■• .........m■■■■ 34 3630 1 17 1100 8.001 600 ■■■•■•••■■■11 : : : : : ,..: :•:• 11J 2500 ' iwwwwimmomosumlim■■ :::::::::::::; :::::::::::;;: momm•■■•■■■ : : : : : : :•,. : : :.•: .•:, ; ; ; : ; ;;;;:i:i:! , .:;:;:i.:::i:: 8.50 600 W ■••••••■■....■ m ■■"....•■■•....= :,,,,,:::::::, ::... ,:,:, ------ . “ (1) 2000 ■■■■••■■•• :::::::::.:: :::::::::::::: : 9.50 590 0 10.00 590 • ui , ■■■■•••■■ :::::::::::::: :;:;:;:::;:::: 11■■■■111111■MMINI ;.......; • : • : • .:i:i i .. ■,1,s,..... „ „„„s.s.., re 0. 1500 , ■■■■■•••■ ::::,,,,,:::::: ::::::,:,:,:, ■■■iimmimmmioNwo :, . ,. ■■■■•■•■•=m1 .'......• ... n 1000 ' ""ni 1■•■■•••••■ ::::::::::::::: :,,,,,,,,,,,, .t1 ••••■■■•■ ,,,,,,,:::::::: ::::::,,,'••,: ..,,„: 0.,,, , _ „S,1.1, ■ 11111"i...1.1 . 111111 • 500 ■■■•••■■■ •,,,,,,:;:::;:: ::::::::;:;:;: misix■■■■■ :::::,:,,,,,,,, :::::::::::::, moomiNew■■■•■ :•:•:•: : : : : : :•:•:•: - _ - 0 ,,"' ' • , ■■••••■■•■ 1• ' • o 1 2 3 4 0 5 10 15 20 25 30 ' ' ' ''.' '' ' •''''' '.;:;:;::; ::;:;;;;;;;;;;; Barrels Shut-In time, Minutes Volume Volume Volume Volume ImItam'CASING TEST - LEAK TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 3.4 Bbls :;:iiiiiiii1Bbls 1.7 Bbls ii:;:',:::::IBbls Comments: UL.1.3- i ZZ our ubg ri riukti.xls Summary • • CD3-122 Intermediate Well: CD 22 7" 26 ppf L-80 BTC=rn Casing Date: 1122/2010 c1ifir Cono ips Rig: Doyen Rig 19 Alaska, Inc, Depth Jt Number Joints Well Equipment Description and Comments ;.: Length Tops Page 1 . s .• IE • T00:0$0106: RKB to Casing Flange (Load shoulder 34.53') (LLDS 33.61') 33.61 1111111111L., FMC 7" Mandrel hanger 1.29 33.61 7", 26#, L-80, BTC-m Casing Pup jt Pin x Pin 1.27 34.90 Jts 98 to 224 127 Jts 7 ", 26#, L BTC Casing 5156.50 36.17 HES 7" Stage Collar 2.43 5192.67 Jts 4 to 97 94 Jts 7", 26#, L BTC Casing 3802.83 5195.10 HES Shut Baffle Collar 1.01 8997.93 Jts 3 to 3 1 Jts 7", 26#, L BTC Casing 43.44 8998.94 HES Sure Sea U Float Collar w/ By Baffle Adapter 1.00 9042.38 Jts 1 to 2 2 Jts 7", 26#, L BTC Casing 84.52 9043.38 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 9127.90 9130.02 8-3/4" Hole TD 9140' MD / 6958.9 ' TVD, Hole angle 86.28 deg 9130.02 7" Shoe @ 9130.02' MD / 6958.3' TVD/ Hole angle 86.28 deg 9130.02 9130.02 Total of 91 Straight Blade centralizers (7" x 8-3/8") - 5 Stop Collars 9130.02 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 9130.02 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 9130.02 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 9130.02 1 Straight Blade centralizer per jt on jts # 4-#30 floating 9130.02 9130.02 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. #97 9130.02 1 Staight Blade centralizer w/ stop 10' Stage Collar -Jt. #98 9130.02 1 Straight Blade centralizer per joint floating # 99 thru #123 9130.02 9130.02 1 on 3 jts Across Shoe jts # 159, #160 & 161 9130.02 then 1 every other jt # 163 to # 223 9130.02 9130.02 9130.02 9130.02 9130.02 Planned: 230 jts in pipe shed / 224 jts to run. 9130.02 6 joints left in the shed 9130.02 9130.02 9130.02 Remarks: Drifted w/ 6.17" plastic rabbit Up Wt 285 K Average MU torque= 8000 Ft lbs Dn Wt 180 K Block Wt 74 K Supervisors: Fred Herbert / Granville Rizek u , IIII,II 0 1 6 ' � 'l' P; + Cement Detail Report idlik � II� 11l :.� Ihwllr &W+ 6 ,I, G Ii� . , p p iu l it s �I I i „ i l Ili d �� i ..M.I��Igil CD3 - 122 ConocoPhillips L 1 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Gement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 1/22/2010 21:50 1/23/2010 02:15 CD3 - 122 Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushll. Shut down and load shut off plug. Dowell mix and pump 56.7 bbls Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbls before bumping plug. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on FMC hanger @ 2336 hrs 1 -22 -2010. Held press 4 min, bled off press - floats held. Load Halliburton closing plug f/ 2nd stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Circ a total of 332 bbls. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbls © 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbls (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump @ 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush @ stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 Cement Stages Stage # 1 ._ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Cement 7" intermediate 7,786.0 9,140.0 Yes 0.0 Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 6 410.0 930.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls © 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushll. Shut down and load shut off plug. Dowell mix and pump 56.7 bbls Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbls before bumping plug. PU wt 280 to 285k, SO wt 180k. l Bumped plug © 2341 hrs 1 -22 -2010. Landed on FMC hanger @ 2336 hrs 1 -22 -2010. Held press 4 min, bled off press - floats held. Load Halliburton closing plug f/ 2nd stage. Cement Fluids & Additives Fluid , l Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 5,652.0 6,719.0 40.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid.... . Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 6,719.0 7,786.0 40.0 Yield (fflsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Intermediate 7,786.0 9,140.0 273 56.7 Tail Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Page 1/2 Report Printed: 2/8 /2010 0 • .1 42 9Egli,, Cement Detail Report Il i,, l w CD3 -122 4 I II I I CcxHCacoPh rtlr Ps llp "`` String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Additives Additive Type Concentration Conc Unit label D046 anifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 disperssant 0.3 %BWOC Cement Stages - - Stage # 2 _ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Isolate Quannik 4,167.0 5,193.0 Yes Yes No Cement formation Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 2 6 270.0 1,425.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Load Halliburton closing plug f/ 2nd stage after checking floats on first stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Circ a total of 332 bbls. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbls (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump © 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush @ stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 Cement Fluids & Additives Fluid _ - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 2,500.0 3,303.7 30.1 Yield (fN /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Flu ►d - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 3,303.7 4,146.7 31.6 Yield (ft'Isack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label °Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surface Tail 4,146.7 5,192.7 187 39.2 Yield (ft' /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 anti foam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 dispperssant 0.3 %BWOC I Page 2/2 Report Printed: 2/8 /2010 0 Oecurity Level: AK Development Daily Drilling Report GII ► z� ri CD3 -122 Report Number: 12 Co'1ocorhilIips ,,.. Rig: DOYON 19 Report Date: 1/21/2010 AFE Type '!` Network/ID # Total AFE +Sup . 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 122 Development FIORD NECHELIK 9.02 12.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,598.86 305,439.47 177,329.86 2,970,961.47 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 24.79 4.11 2/4/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,685.1ftKB Ops and Depth t Morning Report 24hr Forecast Running 7" 26 ppf L -80 BTCM csg @ 1200' Run 7" Intermediaate casing, circ, cement shoe, circ, cement stage collar, R/D cement and casing equip, set packoff, test, change rams, test BOPE equip. Last 24hr Summary Continue to backream out f/ 7864' to 7769', Circulate f/ 7769' to 7480', Trip in the hole f/ 7480' to 9100'. Wiped numerous areas from 8372' to 9100' (last stand tripped). Make a top drive connection, then ream from 9100' to 9140' (TD). Backream out from 9140' to 8435'. Re- reaming the hole which was wiped clean on trip in. Circulate from 8435' to 8244', Trip in the hole f/ 8244' to 9100'. Make a top drive connection, then ream from 9100' to 9140' (TD). Circulate hole clean,spot casing running pill, pump out laying in casing running pill f/ 9140' to 7769', monitor well- static, pull out of the hole f/ 7769' to 2650', circulate the 9 -5/8" casing clean, monitor well- static, blow down the top drive, pull out of the hole f/ 2650' to 733', monitor well- static, stand back 5" HWDP, lay down the jars, lay down three NM drill collars, drain SperryDrill motor, break hughes 8 -3/4" bit, download Sperry Sun MWD, lay down BHA #2. Pull FMC wear bushing. Make up BOP stack washing tool on a stand of 5" drill pipe, flush and clean stack, washing BOP ram cavities: pumping 650 gpm w/ 380 psi, jet pssum belly and flow line. Blow down the top drive, remove tool, set back a stand of 5" dp. Pre job safety meeting on changing top pipe rams. With blind rams closed, change top pipe rams from 3 -1/2" x 6" variable to 7 ". General Remarks Weather Head Count No Accidents / No Spills -30 °, Wind SW @ 10 Mph, 10 mile vis 52.0 Supervisor Titre Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log Start -- - End= Dur -__ . _ _ Time Depth Start Depth End Time _ Time (hrs) Phase = Op Code Activity Code P-T -X . ° Trial Code Trial Class. ('RKB)` MO) Operation Ef 00:00 00:15 0.25 INTRM1 DRILL REAM P 7,864.0 7,769.0 Continue to backream out f/ 7864' to 7769', pumping 600 gpm w/ 2080 psi, rotating 60 rpm w/ 10.5k ft lbs of torque. ECD's 10.45 to 10.49 ppg. Pulling speed 17' /minute. 00:15 02:00 1.75 INTRM1 DRILL CIRC P 7,769.0 7,480.0 Circulate while setting back a stand every 30 minutes (2 -3' /min) from 7769' to 7480'.Pumping 600 gpm w/ 2040 psi. Rotate 60 rpm w/ 10.5k ft Ibs of torque. Orient to high side after circulating. 02:00 02:15 0.25 INTRM1 DRILL TRIP P 7,480.0 7,578.0 Trip in the hole f/ 7480' to 7578'. 02:15 02:30 0.25 INTRM1 DRILL OWFF P 7,578.0 7,578.0 Monitor well- static. Blow down the top drive. 02:30 03:30 1.00 INTRM1 DRILL TRIP P 7,578.0 9,100.0 Trip in the hole f/ 7578' to 9100'. Wipe numerous areas from 8372' to 9100' (last stand tripped). Note: Area's which took weight while tripping in the hole: 8407', 8521', 8597', 8617', 8788', 8880', 8998'. 03:30 03:45 0.25 INTRM1 DRILL REAM P 9,100.0 9,140.0 Make a top drive connection, then ream from 9100' to 9140' Pumping 625 gpm w/ 2180 psi. Rotate 50 rpm w/ 10.5k. PU wt 240k, SO wt 178k. Latest BOP Test Data Date - Comment ` == 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/3 Report Printed: 2/8/2010 • •curity Level: AK Development Daily Drilling Report ►. CD3 -122 Report Number: 12 ConocoPf fillips x Rig: DOYON 19 Report Date: 1/21/2010 Time Log Stag . End, Du ; Time Depth Start, Depth End Time Time " (hrs) °° Phase - Op Code Rcti ity Code P-T-x Trbl Code Trial MB) Class. B) " MKS) Operation 03:45 05:15 1.50 INTRM1 DRILL REAM P 9,140.0 8,435.0 Backream out from 9140' to 8435'. Pumping 600 gpm w/ 2030 psi. Rotating 50 rpm w/ 10.5k ft Ibs of torque. Pulling speed 17 to 20' /min. Note: Re- reaming the hole which was wiped clean on trip in. 05:15 05:45 0.50 INTRM1 DRILL CIRC P 8,435.0 8,244.0 Circulate while setting back a stand every 30 minutes (2 -3' /min) from 8435' to 8244'. Pumping 600 gpm w/ 2030 psi. Orient motor to high side. 05:45 06:00 0.25 INTRM1 DRILL TRIP P 8,244.0 8,339.0 Trip in the hole f/ 8244' to 8339'. Blow down the top drive. 06:00 06:15 0.25 INTRM1 DRILL TRIP P 8,339.0 9,100.0 Trip in the hole f/ 8339' to 9100'. Hole is in good shape. 06:15 06:30 0.25 INTRM1 DRILL REAM P 9,100.0 9,140.0 Make a top drive connection, then ream from 9100' to 9140' Pumping 600 gpm w/ 2030 psi. Rotate 50 rpm w/ 10k. PU wt 240k, SO wt 178k. 06:30 08:00 1.50 INTRM1 DRILL CIRC P 9,140.0 9,140.0 Circulate and condition mud and hole @ 9140'. Pumping 600 gpm w/ 2030 psi. Rotate 50 rpm w/ 10k ft lbs of torque. 08:00 09:30 1.50 INTRM1 DRILL TRIP P 9,140.0 7,769.0 Spot casing running pill in the drill pipe. Pump out of the hole, pumping 105 gpm w/ 210 psi, while pulling to lay in the casing running pill from 9140' to 7769'. PU wt 242k, SO wt 178k. Note: Casing running pill: 95 bbls pumpable mixed with active mud, MW 9.8 ppg, Safe Carb 40, Safe Carb 250, G Seal, Alpine drill beads, Soltex, Resinex and loTorq lube. 09:30 09:45 0.25 INTRM1 DRILL OWFF P 7,769.0 7,769.0 Monitor well- static. Blow down the top drive. 09:45 14:15 4.50 INTRM1 DRILL TRIP P 7,769.0 2,650.0 Pull out of the hole from 7769' to 2650'. Monitor well on the trip tank. PU wt 150k, SO wt 175k. 14:15 14:30 0.25 INTRM1 DRILL OWFF P 2,650.0 2,650.0 Monitor well at the 9 -5/8" shoe- static. 14:30 15:15 0.75 INTRM1 DRILL CIRC P 2,650.0 2,650.0 Circulate bottom's up to clean up casing and reduce yield point of mud. Pumping 600 gpm w/ 1520 psi. Rotate 30 rpm w/ 6k ft Ibs of torque. 15:15 15:30 0.25 INTRM1 DRILL OWFF P 2,650.0 2,650.0 Monitor well- static. Blow down the top drive. 15:30 17:30 2.00 INTRM1 DRILL TRIP P 2,650.0 733.0 Pull out of the hole from 2650' to 733'. Monitor well on the trip tank. 17:30 17:45 0.25 INTRM1 DRILL OWFF P 733.0 733.0 Monitor well- static. Blow down the top drive. 17:45 18:30 0.75 INTRM1 DRILL TRIP P 733.0 175.0 Stand back 6 stands of 5" HWDP, lay down the jars. 18:30 19:00 0.50 INTRM1 DRILL PULD P 175.0 83.0 Lay down (3) 6 -5/8" NM Drill collars. 19:00 19:15 0.25 INTRM1 DRILL TRIP P 83.0 83.0 Pick up, drain motor, break bit. 19:15 19:45 0.50 INTRM1 DRILL PULD P 83.0 83.0 Download Sperry Sun MWD. 19:45 20:45 1.00 INTRM1 DRILL PULD P 83.0 0.0 Lay down BHA #2. 20:45 21:15 0.50 INTRM1 DRILL OTHR P 0.0 0.0 Pull FMC wear bushing, clear floor. Page 2/3 Report Printed: 2/8 /2010 �� I I I • •curity Level: AK Development 'ill k ,t ;., I l [i l,; Daily Drilling Report 4 1 I11,Ihuo,1111:10 CD3 -122 itiv 4 0 1 IIIV 11 9 i ttnc�ccsPhitlips Report Number: 12 Rig: DOYON 19 Report Date: 1/21/2010 Time Log _ Start End Dur Time -- -= -= Depth Start - -Depth End Time Time _ (hrs) Phase O Code Activity Code P Trbl Code Trbl Class. (ftKB) (ftKB) - Operation 21:15 22:30 1.25 INTRM1 DRILL CIRC P 0.0 0.0 Make up stack washing tool on a stand of drill pipe. Wash BOP stack pumping 650 gpm w/ 380 psi. Jetting flow line and pssum belly at shakers. Cleaning up BOP ram cavities. 22:30 22:45 0.25 INTRM1 DRILL TRIP P 0.0 0.0 Drain stack, blow down the top drive. Set back stand. 22:45 23:00 0.25 INTRM1 CASING SFTY P 0.0 0.0 Pre job safety meeting on changing top pipe rams f/ 3 -1/2" x 6" variable to 7 ". 23:00 00:00 1.00 INTRM1 WHDBOP NUND P 0.0 0.0 Close blinds. Change upper pipe rams (3 -1/2" x 6 ") to 7 ". Mud Check Data == YP Calc Gel (1.Os) Gel (10m) Gel (30m) - HTHP Fit _ , -_ . Density Temp _ = Solids Cor€ ' Type Depth (ftKB) Dens(iblgal) Vis(s/gt) PV Calc (cp) (lbf /1 DOW) (Ibf /1 f') (Ibf /100ft9 , (IbfltOOft') - _ = (m O Iii, pH = ( (%) LSND 9,140.0 9.80 36 9.0 17.0 6.0 8.0 10.000 140.2 9.7 10.0 w /Inhibycol LSND 9,140.0 9.84 36 9.0 17.0 6.0 8.0 10.000 140.2 9.2 10.0 w /Inhibycol Injection Fluid - __Fluid Source From Lease (bbl) Destination Vendor Manifest Number Note Diesel 20.0 CD3 -305 Water Based Mud CD3 -122 425.0 CD3 -305 Wellbores Wellbore Name Wellbore API /UWI CD3 -122 501032060900 . _ -- Section, Size (in) ! G Act -Top (ftKB) Act Btm (ftKB) StartDate_==- End, Date COND1 24 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Page 3/3 Report Printed: 2/8/2010 • acurity Level: AK Development Daily Drilling Report Pk I'' D IY CD3 -122 ii ul� Ip v Report Number: 13 CanocoPhil lips Rig: DOYON 19 Report Date: 1/22/2010 __- -` AFE Type Network/ID # = =' ' Total AFE +Sup . 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 122 Development FIORD NECHELIK 10.02 13.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,375.22 310,814.69 743,763.22 3,714,724.69 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 25.79 3.11 2/5/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,130.0ftKB Ops and Depth @ Morning Report 24hr Forecast Changing top pipe rams to 3 -1/2" x 7 ". Circulate, cement through stage collar, R/D cementing and casing tools, pull wear bushing, install packoff, test packoff, change upper pipe rams, lay down 5" DP, PU 4" DP, test BOPE. Last 24hr Summary Change top pipe rams to 7 ", PJSM, RU, test to 250 psi and 3500 psi, R/D test equip, install FMC thin wear bushing, PJSM, RU, PJSM, Run 7" csg: MU fist 4 jts, fill pipe w/ Frank's fillup tool, circ 20 bbls, check floats- OK. Con't to run 7 ". Avg MU torque 8000 ft lbs. The first 30 joints have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. Con't to run 7" csg f/ 1200' to 2630'. Circ & cond mud @ 2630'. Con't to run 7" f/ 2630' to 5065'. Between jt # 97 and # 98 is the Halliburton Type HES 7" stage collar (Baker locked). Centralizer floating on Jt # 97 & # 98 between a stop, 10' above and below cementer. Circ & cond mud @ 5065'. Con't to run 7" f/ 5065' to 7507'. Centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. Circ & cond mud @ 7507'. Con't to run 7" f/ 7507' to 9130'. PU wt 300k, SO wt 175k. R/D Frank's FU tool. RU Dowell cement head & cementing hose. Circ a total of 693 bbls, PJSM. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll, Shut down, load bottom plug. Pump another 5 bbls of mudPushll @ 11.5 ppg. Shut down, load shut off plug. Mix & pump 56.7 bbls 15.8 ppg(273 sx) (1.16 cuft/sx) 5.076 gal /sx) cement @ 5.2 bpm avg w/ 400 psi initial and 140 psi final. Drop Halliburton shut off plug, chase w/ 20 bbls water pumping 5.3 bpm w/ 44 psi initial and -17 psi final pressure. Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Recip until 15.8 bbls before bumping plug, final rate 3 bpm, landed on FMC hanger. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. General Remarks Weather Head Count No Accidents / No Spills -24 °, Wind E @ 14 Mph, 10 mile vis 51.0 Supervisor = Title Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log ; Start End -_- Dur ii - Time Depth Start Depth End 'Time T me -== €ttrs) - Phase Op Code Activity Code -_ = P T X Trbl' Code TrbT Class. ('MKB)'' (ttKB) Operation 00:00 00:30 0.50 INTRM1 WHDBOP NUND P 0.0 0.0 Continue to change upper pipe rams (3 -1/2" x 6 ") to 7 ". Blind rams are closed. 00:30 00:45 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Pre job safety meeting on rigging up to test 7" rams. 00:45 01:00 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Rig up to test 7" rams. 01:00 01:15 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Test 7" upper pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. 01:15 01:30 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Blow down testing lines. Rig down. 01:30 02:00 0.50 INTRM1 CASING PULD P 0.0 0.0 Install FMC thin wear bushing (10.75" ID). Lay down the 7" test joint. 02:00 02:15 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on rigging up casing running equipment. 02:15 02:45 0.50 INTRM1 CASING RURD P 0.0 0.0 Rig up to run 7" 26 ppf L -80 BTC -m casing. 02:45 03:00 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on running 7" 26 ppf L -80 BTC -m casing. Latest BOP Test Data -Date _ <. _ ., Cottimen! - = - 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/5 Report Printed: 2/8/2010 • Scurity Level: AK Development Daily Drilling Report I li a ', I C I , i ► # CD3 -122 Report Number: 13 ConocoPhillips Rig: DOYON 19 Report Date: 1/22/2010 Time Log Start End Dur Time Depth Start Depth End Time Time > (hrs),; Phase Qp Code Activity Code - - P-T -X Trbl Code Trbl Class. (ftKB) (ftKB) "'' Operation 03:00 04:00 1.00 INTRM1 CASING RNCS P 0.0 172.0 Run 7" casing: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were bakerlocked. 04:00 04:15 0.25 INTRM1 CASING CIRC P 172.0 172.0 Fill pipe w/ Frank's fillup tool, circulate 20 bbls, check floats- OK. 04:15 06:00 1.75 INTRM1 CASING RNCS P 172.0 1,200.0 Continue to run 7" 26 ppf L -80 BTCM casing. Average make up torque 8000 ft Ibs of torque. 30 jts in the hole. The first 30 joints all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. 06:00 07:30 1.50 INTRM1 CASING RNCS P 1,200.0 2,630.0 Continue to run 7" 26 ppf L -80 BTCM casing from 1200' to 2630' (Jt # 30 to jt # 65). 07:30 08:15 0.75 INTRM1 CASING CIRC P 2,630.0 2,630.0 Circulate and condition mud @ 2630', prior to exiting surface casing shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. 08:15 11:00 2.75 INTRM1 CASING RNCS P 2,630.0 5,065.0 Continue to run 7" 26 ppf L -80 BTCM casing from 2630' to 5065' (Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the 7" Halliburton Type HES cement stage tool. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and the box. A centralizer floating between the pin and 10' above the pin of joint # 98. Then centralizers were installed floating on jt # 99 to # 123. 11:00 12:00 1.00 INTRM1 CASING CIRC P 5,065.0 5,065.0 Circulate and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. 12:00 15:00 3.00 INTRM1 CASING RNCS P 5,065.0 7,507.0 Continue to run 7" 26 ppf L -80 BTCM casing from 5065' to 7507' (Jt # 125 to jt # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. 15:00 16:30 1.50 INTRM1 CASING CIRC P 7,507.0 7,507.0 Circulate and condition mud @ 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. Page 2/5 Report Printed: 2/8 /2010 �� • Scurity Level: AK Development kllillill0 ° '� ,1 1 , " Daily Drilling Report s i� III CD3 -122 crnocPPttlllps Report Number: 13 Rig: DOYON 19 Report Date: 1/22/2010 Time Log Start End Dur Time Depth Start Depth End Time Mine (hrs) (hrs),, Phase _ Op Code - ---- Activity, Code P - T - X = ITrbl - Code Trial Gass - (ftKB) '` (ftKB) Operation 16:30 19:00 2.50 INTRM1 CASING RNCS P 7,507.0 9,130.0 Continue to run 7" 26 ppf L -80 BTCM casing from 7507' to 9130' (Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K PU wt to break over. Landed on hanger @ 1900 hrs. 19:00 19:15 0.25 INTRM1 CASING RURD P 9,130.0 9,130.0 Rig down Frank's fill up tool, blow down the top drive. 19:15 19:30 0.25 INTRM1 CEMENT RURD P 9,130.0 9,130.0 Rig up Dowell cement head and cementing hose. 19:30 21:45 2.25 INTRM1 CEMENT CIRC P 9,130.0 9,130.0 Circulate, staging pumps f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. Pre job safety meeting while circulating. Circulated a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg 21:45 22:30 0.75 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls © 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial to 190 psi final. Shut down, then load bottom plug. Pump another 5 bbls of 11.5 ppg mudPushll. Shut down and load shut off plug. 22:30 22:45 0.25 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell mix and pump 56.7 bbls (273 sx) Alpine tail cement (15.8 ppg) (1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 400 psi initial and 140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pumping 4.5 to 5.3 bpm w/ 44 psi to -17 psi. 22:45 23:45 1.00 INTRM1 CEMENT DISP P 9,130.0 9,130.0 Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Reciprocated f/ 9130' to 9120' until 15.8 bbls before bumping plug, landed on FMC hanger. Slowed to 3 bpm for the last 20 bbls pumped. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. 23:45 00:00 0.25 INTRM1 CEMENT OTHR P 9,130.0 9,130.0 Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. injection Fluid = = Source From Lease (bbl) Destination Vendor Manifest Number = Nate Diesel 35.0 CD3 -305 Water Based Mud CD3 -122 40.0 CD3 -305 Welibores Wellbore Name Wellbore API/UWI CD3 - 122 501032060900 Section Size (in) Act (ftKB) - _ _ Act Btm (ftKB)° Start - Date _ . End, Date COND1 24 37.0 114.0 Page 3/5 Report Printed: 2/8/2010 • Scurity Level: AK Development Daily Drilling Report i d ui olO deli ► it �l� d ill ll i °' �'' CD3 -122 Report Number: 13 Coir ocoPhitlips Rig: DOYON 19 Report Date: 1/22/2010 Section Size (in ',_ Act Top (ftKB) = Act Btm,(ftKB) Start Date End Date SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Casing Strings = String OD _ String Wt -_ Casing Description Run Date (in) (Ibslft) String Grade Set Depth (ftKB ) , Comment Intermediate 1/22/2010 7 26.00 L -80 9,130.0 PJSM on running 7" 26 ppf L -80 BTC -m csg. Run 7" cg: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full joint. 4 jts w/ baker lock. Fill pipe w/ Frank's FU tool, circ 20 bbls, check floats- OK. Con't to run 7" 26 ppf L -80 BTCM csg. Avg make up torque 8000 ft lbs. The first 30 jts all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. Con't to run 7" csg from 1200' to 2630' (Jt # 30 to jt # 65). Circ and condition mud @ 2630', prior to exiting surface csg shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. Con't to run 7" csg from 2630' to 5065' (Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the Halliburton Type HES 7" stage collar. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and the box. A centralizer floating between the pin and 10' above the pin of jt # 98. Then centralizers installed floating on jt # 99 to # 123. Circ and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. Con't to run 7" csg from 5065' to 7507' (Jt # 125 to jt # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163 to # 223. Circulate and condition mud @ 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. Con't to run 7" 26 ppf L -80 BTCM casing from 7507' to 9130' (Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K to break over. Landed on hanger @ 1900 hrs. Quit recip 2336 hrs 1/22/2010 during cement job. Final PU 285k, SO 180K. Cement.,., Intermediate Casing Cement - Started @ 1/22/2010 Type Welibore Cemented String Cement Evaluation Results casing CD3 - 122 Intermediate, 9,130.0ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 7,786.0 9,140.0 3 410.0 (sacks) (bbl) ity ( gal) f ) Top f ) Est Btm - , Fluid _ -,' - ", Class Amount- sacks V bbl } - =_ _- , = = = Dens' (lb/gal) Yield= ft'lsadc . Est T ttKB ;,,, ) . ` -` CW100 40.0 8.40 5,652.0 6,719.0 MudPush II 40.0 11.50 6,719.0 7,786.0 Page 4/5 Report Printed: 2/8/2010 • Icurity Level: AK Development ,�i Daily Drilling Report ; &Ir i11i , CD3 -122 i ,� ��„ - Report Number: 13 ConocoPhtillips ;° Rig: DOYON 19 Report Date: 1/22/2010 Fluid Class Amount (sacks) V (bbl) Density (Ibfgat), Yield (ft' /sack) Est Top (EKB) Est Btm (ttKB Alpine Intermediate Tail 273 56.7 15.80 1.16 7,786 9,140.0 Stg No. Description Top (ftKB) Bottom (ftKB) 0 (end) (bbl /... P (final) (psi) 2 Intermediate Casing Cement 4,167.0 5,193.0 2 270.0 Fluid = Class -- - Amount (sacks) V (bbl) Density (Ib/gal) Yield (ft%sack) Est Top,(tti(S) Est Btm ',(ftKB) CW100 30.1 8.40 2,500.0 3,303.7 MudPush II 31.6 11.50 3,303.7 4,146.7 Alpine Surface Tail 187 39.2 15.80 1.17 4,146.7 5,192.7 I Page 5/5 Report Printed: 2/8/2010 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -122 I Rig:I Doyon 19 Date: I 1/23/2010 Volume Input Pum • Rate: Drilling Supervisor: Fred Herbert / Granville Rizek jPump used: Cement Unit v Barrels Bbls /Strk 0.80 Bbl /min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ■ - Casin • Test Pressure Integrity Test Hole Size: 8 - 3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I 34.2IFt 2801.0IFt -MDR 2484.OIFt -TVD 4172.0IFt -MD 13656.0 Ft -TVD Bbls •si Min •si Bbls •si Min •si Casing Size and Description: 9 - 5/8" 40 # /Ft L - 80 BTC V 0 0 39 0.00 599 Changes for Annular Adequacy Test Pressure Inte • ri Test 1 0.5 144 0.25 547 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 247 0.50 542 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 349 1.00 539 Hole Size is that drilled below outer casing. MEM 4 2 437 1.50 537 Use estimated TOC for Hole Depth. MIMI 5 2.5 516 2.00 535 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 579 2.50 53 Estimates for Test: 672 •si 0.3 bbls 7 3.5 633 3.00 53 v v 8 3.75 648 3.50 529 EMW = Leak -off Pressure + Mud Weight = 648 + 9 8 PIT 15 Second 9 4 622 4.00 528 0.052 x TVD 0.052 x 2484 Shut -in Pressure, psi 10 4.5 617 4.50 527 EMW at 2801 Ft -MD (2484 Ft -TVD) = 14.8 547 15 5 613 5.00 526 1000 20 5.5 602 5.50 525 25 6 602 6.00 524 ■■■■■■ 30 6.5 602 6.50 524 7 599 7.00 523 ■■■■■■ 7.50 521 IMINEEll 8.00 520 8.50 520 cc • • 9.00 519 N 500 ■■■ 10.00 517 u) 111111..1111. a cc /®11-11-.-- ■■■■■■ 1..1111.11 0 .11111.111111. 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 - - Barrels Shut -In time, Minutes Volume Volume Volume Volume Ilt- 'CASING TEST - M - LEAK - OFF TEST 0 PIT Point Pum • ed Bled Back Pum • ed Bled Back 0.0 :bs =•Is 7.1 =bls :•s Comments: Surface Casing FIT @ 18.1 PPG EMW - - 7" Casing Shoe @ 9130' MD (6958' TVD) CD3 -122 OA LOT 01 -23 -10 .xls Summary ( if \ Z ' �CxM1 B SEAN PARNELL, GOVERNOR �T ALASKA. OIL AND CAST 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 J.G. Samuell Drilling Engineer h � ConocoPhillips Alaska P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, CD3 -122 c (� Sundry Number: 312 -067 �� ,f . N .) MA Dear Mr. Samuell: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above- referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 0 Daniel T. Seamount, Jr. `�'� Chair DATED thisa day of February, 2012 Encl. gut I se AK RECEIVED STATE OF ALASKA Z'" ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 1 2012 ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 Alaska Oil & Gas Cons. Commission 3. Permit to Drill Anchorage . 1. Operator .— — - Name: 2091530 ConocoPhillips Alaska 4. API Number: 50- 103 - 20609 -00 • 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -122 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD3 110, CD3-106, CD3-111, CD3-112, CD3-113, CD3-114, CD3-115, CD3 Torok and Seabee formation, shale, siltstone and sandstone 118, CD3 -117, CD3 -121, CD3 -123, CD3 -125, CD3 -199, CD3 -128 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation - None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1250' MD / 1239' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 4832 bbls as of 2/14/12 / densities range from diesel to 12# /gal 2,106 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ❑ Cement Bond Log (if required) ❑ FIT Records w /LOT Graph El Surf. Casing Cementing Data ❑ Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the bes -, my knowledge. Signature: � .:r t Title: D/ � � f, ` h 6'1 lr2-e e r Printed Phone Name: J.G. Samuell Number: 265 -6309 Date: 21211 1Z- Commission Use Only LOT review and approval: ,2 / 2 -� / (G.- Conditions of approval: PP f t Subsequent form required: S � 2 3 Approval number: 5` 1'43 (01 APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 2...1 1112 4 AD Rev. 6/2004 RUCTIONS ON REVERSE A l smit in Duplicate Form 10 03 .�.,� INSTRUCTIONS ub , ),Ii>�.C�. Annulus Disposal Transmittal Form - Well CD3 -122 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD3 -122 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1250' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 1Vlarch 15. 1999) 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2,106 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3 -119, CD3- 127,CD3- 130,CD3 -120 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. SURFACE CASING SHOE SEPARATION FROM CD3 -122 CD3 -122 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 387238.8 6004125.0 is ance Ann. from Surface csg. Surface Details CO Disp. Object Shoe X Surface csg. Surf LOT casing TVD Annular Wells AOGCC Permit # Permit Date Source well Ann. Vol. ** Start Date End Date well Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments CD3 -108 - Y = ' _.../ ■111101 -moll/ ■INIIIMIEM 389300.3 6004986.4 =Ma IIIIIIIIMEa MEM not for annular 1 18 11 -al CD3 -110, CD3 -111, CD3 -112, CD3 -307, CD3 -109 Y 306 -020 1/20/2006 CD3 -302 6463 1/20/2006 3/4/2007 1802 388917.3 6004780.2 18.0 2414 16.0 Extended 10 70000bbI, ex. 03/17/07 603 -110 Y 1•" 111. 1111. " -- 1453 388563.7 6004720.7 13Ei MICE MBE EIMZIE=IMIII11111111111111111= CD3 -114, CO3 -111 Y 307- 066 2/21/2007 CD3 -301 26674 3/20/2007 4/20/2007 826 387821.0 6004710.6 17.4 2469 14.6 CO3 -113, 003- 107 /00 603 -112 Y 307 -002 111. '. 307 32007 1/22/2007 3/16/2007 >. 387406.8 6004382.6 18.0 2485 15.1 Also known second annlus, CD3 - 107/307 Y 2392 389627.9 6004245.8 18.2 2479 15.3 after cut t and .ull o.erations •ull erati rations Feb 2007 CO3 -113, CD3 -118, _ CO3 -303, CD3 -302 308 -036 CO3 -107L1 56647 2/12/2008 1/1/2010 1614 388815.4 6004469.9 18.0 2505 15.0 CD3 -316, 003- 113 307 -067 3/20/2007 CD3 -316A 31964 1/15/2008 3/20/2008 457 387636.7 6003901.1 18.0 2475 16.3 CO3 -114 ©� O 11 111111...- -il pirlifilWilli 4 6003781.8 CD3 -301 =' 1902 388541.7 6005510.5 16.2 2493 15.1 Low surface shoe test 003 -305, CO3 -316A ® 308 -127 NifirXM 003 -115 31881 1/11/2009 2/16/2009 1729 388868.2 6003548.0 18.0 2476 15.9 CD3 -303 308 -426 12/15/2008 CD3 -117 23833 2/14/2009 3 /27/2009 2861 390091.0 6003906.6 18.0 2488 15.9 CO3 -118 Y - . �I♦ �� 1080 386456.5 6003425.3 2489 ® Low surface shoe test CD3 -305 Y 309 -379 12/1 /2009 32000 111111111115=MEM 390145.4 6003158.0 MEM immrsa mum 003 -115 Y 309 -087 =' € -,' -` 003 -304 32000 MEM= MEM 386822.0 6003553.0 CD3 -304 Y 309 -380 12/1/2009 3149 111111=MMEEfil 390789.9 6003209.3 mina Immfigi mgaga 003 -117 Y ■1■111- ® 386471.4 6003320.0 16.2 2447 14.80 CD3 -106 Y 388447.6 6004482.6 17.0 2475 15.00 003 -121 . Y 387435.6 6004569.9 16.3 2457 14.90 CD3 -122 Y 311 - 035 2/29/2012 CD3 -128 6000 2/2/2012 2/29/2012 1111111113 387238.8 6004125.0 16.3 2484 14.30 CO3 -123 Y . 310 386932.7 6004176.7 1.5? 2468 15.20 Low surface shoe test CD3 -124 Y 310 -088 4/8/2010 31996 2/1/2010 3/1/2011 1454 386016.2 6003338.3 man mmHg 14.60 Low surface shoe test 003 -125 0 �� -�� -111MINCI 386677.0 6003842.4 MOD ■30221 MOM CD3 -128 N CD3-198 N � 1416 6003642.6 Low surface shoe test 691 387876.3 6004392.6��- CD3 -199 N 691 387876.3 6004392.6 MiIII LEI =BM 03 -127 allill 11.11111.1111111111111111111111111.1.1111111111.111.111111111111M1111111111111 1 3882 Planned Wells 03-119 INIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIMIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIII 2287 X774.1 �. r• -,, I f;c _ 111111111111111 - IMZIMEMIIIIIIIIIIIIIIIIIIIIIIIIIIIIII Planned Wei *' 130 M� -- * Lateral distance in feet, between surface casing shoes, in the X -Y plane ** As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes C D 3 12 2 Name /ELLBORE TARGET DETAILS (MAP CO-ORDINATES) TVDSS +N1 -S +E/ -W Northing Easting Shape 15:35, February 20 2012 CD3- 113 _SouthwpXX Top Nechelik 6902.00 - 314.44 - 3743.66003269.01)524239.00 Circle (Radius: 100.00) Quarter View CD3_713_SuuthwpXX Toe 7025.00 - 5130.66 - 176.4996400 001527733.00 Circle (Radius: 100.00) N 6 4 0 . G0 ,5,��`L GC' '0 Ci6Y 0 ,� , % 90 9 Q0 ,�`t�Q G 03 %� O 3 N09 G GO g A 11 t 03106`' G, ° L► , , A • o ? ..e 030 ?�4 . , 1 ° 1650 � W GO GO 110 0 0' 1 O o CD3 -122 Surf. *11 /GO N / in LO 3 `� Shoe '<k Go3 so� Go pi.will . 550 i O th `- / Z 09• W - G by ' o 0 ' - allbl c.) . G O5- 12 / `� o GO B 50 - _ CD3-128 _(Interme � j G Oh Gp , 5 ;3 G 03. 0 GOB, Nti� 0 - 00 co'''% Gam: Goy -2750 -2200 -1650 -1100 -550 0 550 1100 1650 West( -) /East( +) (550 ft /in) STATE OF ALASKA FEB 1 5 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION,=, . ffi3 ry s; F+ � a e 20 AAC 25.080 3, 1. Operator 3. Permit to Drill ` " " '`� Name: 2091530 ConocoPhillips Alaska 4. API Number: 50- 103- 20609 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 - 122 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD3 -110, CD3 -106, CD3 -111, CD3 -112, CD3 -113, CD3 -114, CD3 -115, CD3- Torok and Seabee formation, shale, siltstone and sandstone 118, CD3 -117, CD3 -121, CD3 -123, CD3 -125 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1250' MD / 1239' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 357 bbl densities range from diesel to 12# /gal 2,106 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1 - Mar - 11 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) El FIT Records w /LOT Graph 0 Surf. Casing Cementing Data 0 Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Su.P6ev is I N Signature: �� ���� 2 ! Title: 024 L L t to L .) Cif NE2 Printed Phone Name: Liz Galiunas Number: 265 -6247 Date: Commission Use Only Conditions of approval: LOT review and approval: e.7 - RI - 11 Subsequent form required: / Approval number: .30 - , OBY THE APPROVED COMMISSION Date: 3I 1 )(1 Approved by: ' COMMISSIONER THE Form 10 -403AD Rev. 6/2004 INSTRUCTIONS ON REVERSE �tJPL. 1 / ) ) A In Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh • I I • ps Telephone 907 - 276 -1215 RECEIVED February 21, 2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Atka Oil & Gas Coos. Commission Anchorage, Alaska 99501 -3539 Atien01 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3 -122 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests to reauthorize a new permit for CD3 -122 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The well is currently being used for annular disposal operations. CD3 -122 was originally permitted for annular disposal on March 1, 2011 per Sundry #311 -035. When this permit expires on Feb 29, 2012 a total volume of approximately 6,000 bbls will have been injected. - - Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. List of wells on CD3 Pad and the lateral distance from the surface casing shoe. 3. Updated Plan View of Adjacent Wells 4. Copy of CD3 -122 annular disposal permit #311 -035. 5. Information regarding remaining wells within 1 /4 radius included in sundry package: CD3 -128, CD3 -199 6. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations Information already at AOGCC from previous Sundry: 1. Surface and Intermediate Casing Description 2. Surface and Intermediate Casing Cementing Report & Daily Drilling Report during cement job ' 3. Pressure Calculations for Annular Disposal 4. Casing and Formation Test Integrity Report (LOT at surface casing shoe). ' 5. Information regarding wells within 'A mile radius at AOGCC (total of 12 wells): CD3 -110, CD3 -106, CD3 - 111, CD3 -112, CD3 -113, CD3 -114, CD3 -115, CD3 -118, CD3 -117, CD3 -121, CD3 -123, CD3 -125 The initial annular LOT (14.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (16.3 ppg v' LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact J.G. Samuel] at 265 -6309; Chip Alvord can also be reached by calling 265 -6120. Sincerely, J.G. Samuell cc: Drilling Engineer CD3 -122 Well File Chip Alvord ATO -1577 Sharon Allsup -Drake ATO -1530 Note to File CRU CD3 -122 (PTD 2091530) February 27, 2012 Re: ConocoPhillips' Application for Sundry Approval to Re- authorize Annular Disposal of Drilling Wastes within Well CD3 -122 Request ConocoPhillips requests approval to continue to dispose of waste fluids generated through drilling operations by injection into the 9 -5/8" x 7" annulus within well CD3 -122. When the current approval expires on February 29, 2012, ConocoPhillips will have injected about 6,000 barrels of waste into the well. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at about 2,685' measured depth (- 2,436' true vertical depth subsea, or "TVDSS" ), near the base of a 400 -foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 125' from the wellbore. CD3 -113 (about 150' away) is the only well that may be affected by annular disposal operations in CD3 -122. CD3 -113 was approved for annular disposal of wastes in 2007, and to date that well has received about 32,000 barrels of injected waste materials. Discussion CPAI's application was reviewed along with records and well logs from Colville River Unit (CRU) wells CD3 -108, CD3 -114, and the Nechelik 1 exploratory well. An index map is provided in Figure 1, below. The CD3 -122 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, Alaska (ConocoPhillips) the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3 -122 that extends downward from the 9 -5/8" surface casing shoe, which is set at about 2,685' (- 2,436' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 7,494' All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness, unless otherwise noted. For clarity, depths expressed as true vertical depth below sea level will be preceded by a minus sign and followed by the suffix "TVDSS." CD3 -122 February 27, 2012 Note to File Page 2 of 5 (- 6,235' TVDSS) . This annulus lies within Section 5 of T12N, R5E, Umiat Meridian (see Figure 1), and it is located more than 2 miles from the current external boundary of the CRU. The section of annulus in CD3 -122 that will most likely accept the injected waste fluids (likely receptor interval) is a portion of the Seabee formation that extends from about 2,735' to 2,803' (- 2,475' and - 2,529' TVDSS; see Figure 2, below). This 54 -foot thick interval contains numerous 1- to a- foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 20 feet. On the well log from CD3 -114, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9 -5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9 -5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). The 9 -5/8" surface casing shoe lies near the base of a 480 -foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 55 -foot thick interval of siltstone that is also continuous throughout the area. This interval, which lies between about 2,953 and 3,023(- 2,648' and - 2,703' TVDSS), and two similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. '/ - _ CD3.112 _ - {. t Di -1 07 // R 2�}FI( 5 _ CD3 - 113 \ \ \\ •' 1 1.D3114 1 35 I 0 033 115 \ 4 ! CD3 -302 \ ._ Q \ CD3 -118 \ CRU CD3 -122 CO3;307 4 _�__. r \ Annulus 0 C CO3 -117 V 1 C63 -124 0 DUO 1A \ \\ r ■ ✓ / 3 1 .- .-, i -- .i���3 CD 316 FIORD 1 J — ..-- , Most Likely Receptor CD3 -' 14 � •- i \ Interval 0 Area of Review (highlighted with red) -1' I (shaded blue) V GD3 -121 '' 1 (" S D3- — — - CD s c:112 • Surface casing shoe Cement top 0 Cut 485 - _127 .. Figure 1. Index Map (The path of the cross - section shown on Figure 3 is depicted by the magenta- colored line) 2 Top of cement estimate was determined by G. Schwartz, AOGCC, and is recorded in AOGCC spreadsheet \\Doaancogcfps0 1 \ Shared\ AOGCC \Common\tommaunder\aa2009 0712 Working -Well Cement Current.xls worksheet MIT II, PTD 209 -153, column titled 30% Excess TOC. I CD3 - 122 February 27, 2012 Note to File Page 3 of 5 In vicinity of Drill Site CD3, the base of permafrost occurs at about - 1,200' TVDSS, which is about 1,275' shallower than the top of the likely receptor interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. Correlation Depth Resis Porosity OR <MD ResD(RPD) RHOB -10 API 24C 0.2 OHMM 201 .65 G/CC 2.65 'Sand - SE - Sh TVDSS> 12 Re 201 ow Poro SP(N /A) ND ResS(RPS) NPOR -100 100 12 OHMM 201.0 C Upper <MD DTCP(NJA) Confining 70 7C Strata — * i_ L I UU Most Likely—{ Iiiik n Receptor 2800 MI Interval for at _ iii .. Disposed 2900 'IMF i Fluids " „ �/ '�■/ / 11, 1 irnm„1 NMI , . ,� ■ u l it. 11. - =1- S=/i/n .�i llia - - 11' '■n1111 IIIMEMEM - _ Lower 3100 �/ /1111 -- lIIII�...11iil� Mil — Iff /111 llr: 11 r� Confining —o. 0' = Strata 3200 _ - -� ./.11111 i . simi simmil, N .. - .1111 11111 - 3300 11,0 111111111--- 3400 . UU UII z: + ii::. °nn ar ">I. 3500 ui li/111.. 2 , 1- si mill•.. — tmall 1 II 3600 -3000 3700 'n0 1 1�rr/s i 11 3$00 a maauuIn1111111/ 11• v IN_ / ■UIN ■i1u y _ - t —� / /in.- n ---4 111. .. 3900 t UM= .:.. iiin E ., , 4000 1iPi'I1111.11111 1 "i` 111 • 1 1111H1 .1/ 4100 t� a/ /11,11 l 1 � 1 ■n 111 1 1 111 • / /1 /,i 4200 Iu ,�i.u�u'I .t.E i 4300 Figure 2. CD3 -122 Well Log Displaying Affected Intervals CD3 -122 February 27, 2012 Note to File Page 4 of 5 1811490 2070330 2091530 2050330 SW 501032002000 I 11620 ft 501032054400 405 ft 501032060900 3466 ft 501032050700 NE , , 4 -I 4 ■ 1 ■ SOHIO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 COLVILLE RIV UNIT CD3 -114 CRU CD3 -122 COLVILLE RIV UNIT CD3 -108 2340 FSL 814 FWL 3960 FNL 2703 FEL 3998 FNL 1088 FEL 1349 FSL 816 FEL TWP: 12 N - Range: 5 E - Sec. 18 TWP• 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 - - _ "" u A .vo ,. t_ 1000 44 - �I . '". 1000 .4 — li so .. j , Upper r A ' 9-5/8" Casing Shoe Confining — Strata 500 a - -- 500 _ — 1 — I l k " " " " _ Receptor �" Air " _ interval - sa 0 - L ower " 0 "" . - " Confining �" - (1 g "" -° - Strata � iifi l' -500 EE : I ..., .. -500 1 # . -1000 - - "" - -... } } ? T -1000 ..,, -)' :- - '"° TD =18601 l'i 1D=18915 7 TD =10018 TD =15364 Figure 3. Stratigraphic Cross - section from Nechelik 1 TO CRU CD3 -108 Nearby well CD3 -114 is the only well that was mud logged on Drill Site CD3. In CD3 -114, methane was first encountered at about 1,115' (- 1,050' TVDSS). So, the entire proposed disposal zone likely contains small amounts of gas. The shallowest oil show encountered in well CD3 -114 was observed at 6,050' (- 4,413' TVDSS), about 1,830' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of "trace" quality. This instance is judged to represent only small amounts of residual (non- mobile) oil. So, at Drill Site CD3 the likely receptor interval does not contain potentially commercial quantities of oil or gas. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3 -122 that will be affected by the proposed annular disposal operations. There are about 15' of porous sandy siltstone and silty sandstone beds within the likely receptor interval, according to a count using the CD3 -122 February 27, 2012 Note to File Page 5 of 5 gamma ray curve from CD3 -122. Neutron and density porosity well logs were recorded across the proposed disposal interval in nearby well CD3 -108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values and assuming piston -like displacement of native formation fluids around the wellbore, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 125' from the wellbore (see Figure 4, below). At the level of the likely receptor beds, the closest wells to CD3 -122 are the surface -cased portion of CD3 -123 (50' away, with the CD3 -123 surface casing shoe about 300' away), CD3 -113 (150' away), CD3 -125 (200' away) and CD3 -112 (300' away). CD3 - 113 is the only well that may be influenced by annular disposal operations in CD3 -122. CD3 -113 was approved for annular injection operations in March 2007, and to date that well has received about 32,000 barrels of injected wastes. Injected Fluid vs Affected Radial Distance CD3 -122 Wellbore (assumes 15' aggregate injection zone thickness and 28% porosity) 300 250 0 .0 0 200 E 0 0 Ws 150 6 l0 100 0 0 0) : 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3 -122 Annular Disposal Summary The limited volume of rock that will be affected by this continued proposed disposal injection program likely contains some gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. Beneath Drill Site CD3 there are no freshwater aquifers, and the interval that will receive the injected wastes does not contain potentially commercial hydrocarbons. Correlative rights are not a concern because the open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines. CD3 -113 is the only well that may be affected by fiJ annular disposal operations in CD3 -122. CD3 -113 was approved for annular disposal of wastes in 2007, o � T and to date that well has received about 32,000 barrels of injected waste materials. / Sr Y I re ; end approval of continued annular disposal operations in CD3 -122 to a limit of 35,000 barrels. 1 1- 3 14 avies Senior Petrole Geol /.� ..Z2/ k ierfre'r 11 Note to File CD3 -122 (209 -153 312 -067) Colville River Unit (Fiord) ConocoPhillips Alaska, Inc ConocoPhillips has made application to re- authorize annular disposal in the subject well after one year of disposal and a total of about 6000 bbls of annular injection. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD3 -122). -- 9 5/8" Surface casing was cemented to surface successfully with good returns throughout. No problems were reported. Approximately 58 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 90% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 1/16/10 , the pressure slope rises smoothly to -15.5 EMW and continues at a slightly shallower slope to 16.3 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 14.1 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Good returns were noted and the casing was reciprocated. Qannik zone was covered in the second stage (40bbls) of the cement job. TOC for the second stage is estimated to be at 4200' md. - -An initial injectivity test ( LOT #1) down 7" X 9 5/8" annulus was conducted on 1/23/10. Pressure steadily increases until the break at 14.3 EMW. The pressure increased with additional pumping to 15 ppg EMW. During the observation period, the pressure declined to 13.0 ppg EMW. - - A second LOT of test was conducted on 1 -27 -11 to recheck the pressures and OA status to pumping. The data was suspect so the commission requested another LOT . The results of LOT #3 (done 2- 28 -11) are as follows: Pressure steadily increases until the break at 14.0 EMW. The pressure increased with additional pumping to 15.1 ppg EMW and remains stable here. During the observation period, the pressure declined to 13.8 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity - -There are several wells within 1 /4 mile radius of CD3 -122. The surface shoe of CD3 -112 is closest, about 308' distant. CD3 -123 is 310' and CD3 -114 is 405' distant. AD was approved for CD3 -112 in 2007. There are no identified issues with any of the proximal wells. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. F7` Guy Schwartz Sr. Petroleum Engineer AOGCC February 28, 2012 G:\AOGCC \Common \tommaunder \Well Information\By Subject\Annular Disposal\ 120228_CD3 - 122.doc CD3 -128 Information Casing Detail Well: CD3-128 9 5 464 36# L J LITCM casino Date: 4114/2011 onoc ph . C ips ... i t Rig: Doyon 19 Alaska, his. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 ........... ...•...............• ............................. ::::•:•:•:•:•:•:•:•:.. - - - RKB to Top of Landing Ring 36 - 40 111111111111111111111}NEVIIIIII FMC 9 5/8" Casing Hanger 2.20 36.40 Jts 38 to 72 35 Jts 9 5/8", 40.0#, L BTC Casing 1415.80 38.60 Jts 4 to 37 34 Jts 9 5/8", 36.0#, J BTC Casing 1417.35 1454.40 Jts 3 to 3 1 Jts 9 5/8", 40.0#, L BTC Casing 39.23 2871.75 HES 9 5/8" Super Seal H Float Collar 1.19 2910.98 Jts 1 to 2 2 Jts 9 5/8", 40.0#, L BTC Casing 74.58 2912.17 Ray Oil Tools 9 5/8" Silver Bullet Float Shoe 2.29 2986.75 2989.04 2989.04 12 1/4" hole TD 2999' MD 2456' TVD 2989.04 9 5/8" casing 2989.44' MD 2452' TVD 2989.04 2989.04 2989.04 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 2989.04 1 Bowspring Centralizer on stop collar 10' below the box of joint # 2 2989.04 1 Bowspring centralizer on stop 10' above pin on joint # 3 2989.04 1 Bowspring centralizers on joints # 4-13. 2989.04 1 Bowspring centralizer every othe rjt f/ # 15 to # 69 2989.04 2989.04 2989.04 2989.04 82 jts. casing in shed - 72 jts to run 2989.04 Last 10 jts. stay out 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 2989.04 Remarks: Up Wt 160K Dn Wt 125 K Block Wt 70 K Supervisors: Don Mickey / Dick MaskeH i i i I �� i rf4 x il Cement Detail Report W d 4 ;:�'�,�" CD3 -128 Wii IlW i i i ConocoPttillips I °u String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/9/2011 17:00 Cement Details Description Cementing Start Date Cementing End Date Welibore Name Surface Casing Cement 4/14/2011 12:45 4/14/2011 15:30 CD3 - 128 Comment Cement Stages =_ Stage # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement 38.6 2,989.0 Yes 38.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 550.0 1,120.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented 9 5/8" casing as follows: Pumped 70 bbls 10.0 ppg mud w/ nut plug & 35 bbls biozan water w/ nut plug for marker w/ rig pumps - Switched over to Dowell - Pumped 3 bbls water- Tested lines to 3270 psi - Aligned valves on cement head to drop bottom plug - Dropped bottom plug w/ 50 bbls 10.5 ppg MudPush @ 4.7 bbls /min @ 150 psi - Mixed & pumped lead slurry (AS Crete) @ 11.0 ppg - pumped 290 bbls and observed nut plug marker @ shakers - pumped down surge can - 300 bbls total lead pumped (822 sks) - Switched over to tail slurry ( Class G w/ 0.2% D046, 0.3% D065, & 1% SOO1) & pumped 48 bbls (231 sks) @ 15.8 ppg - Dropped top plug w/ 20 bbls water f/ Dowell - Switched over to rig pumps & dispalced cement w/ 202.3 bbls 10.0 ppg LSND mud @ 6 bbls /min @ 700 psi - Slowed pumps to 3.5 bbls /min for last 12.3 bbls @ 550 psi - bumped plug w/ 1120 psi - CIP @ 1530 hrs - Checked floats OK Full circulation & reciprocation throughout job - 38 bbls 11.0 ppg cement returns to surface Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 38.6 2,489.0 822 G 300.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 2.05 7.34 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,489.0 2,989.0 231 G 48.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/20/2012 nh Security Level: AK Development A � Daily Drilling Report 011 i CD3 -128 ConoPhil liips � 0 iIVlr 1 �: Report Number: 6 !'41fa6r.=. Rig: DOYON 19 Report Date: 4/14/2011 AFE Type ' Network/ID # I Total AFE +Sup 10302125 8,450,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 128 Development FIORD KUPARUK 3.70 6.0 0.00 2,999.0 2,999.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,189.95 57,324.68 482,455.95 1,295,015.68 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/9/2011 4/11/2011 28.80 27.31 1.49 5/7/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,989.0ftKB Ops and Depth @ Morning Report 24hr Forecast PU 5" DP. Approx 141 of 255 jts PU at 05:00 hrs. PU DP. Test BOPE. PU BHA #4 & 5" DP. RIH. Test csg to 2500 psi. Drill out. FIT. Drill 8 3/4" hole. Last 24hr Summary RU to run 9 5/8" casing. MU shoe track. Run 72 jts casing to 2989' MD. Circ & cond mud. Pump 300 bbls LiteCrete lead and 48 bbls Class G tail slurry. Displace and get 38 bbls cmt returns to surface. NU wellhead & BOPE. PU 5" DP. General Remarks Weather Head Count No incidents. No injuries. No spills. Rig & camp on hi -line power. - deg. Wind SW @ 9 mph. WC - deg 49.0 Supervisor = = Title Don Mickey, Rig Supervisor Rig Supervisor Dick Maskell, Rig Supervisor Rig Supervisor Time Log - Start End. Our Time i' Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code '.i P-T-X' TrbiCode Trbf Class, (ftKB) `i - (ftKB)- - -- ! Operation 00:00 01:15 1.25 SURFAC DRILL PULD P 0.0 0.0 Finish LD BHA components Break off bit. Dull grading: 1- 3- BT- 2- E- 1 /8- ER -TD. Clean & clear floor of BHA components. 01:15 02:45 1.50 SURFAC CASING RURD P 0.0 0.0 Bring casing tools to rig floor and RU to run 9 5/8" surface casing. 02:45 03:00 0.25 SURFAC CASING SFTY P 0.0 0.0 PJSM for running casing 03:00 07:15 4.25 SURFAC CASING RNCS P 0.0 1,650.0 Ran 9 5/8" 40# L -80 & 9 5/8' 36# J -55 casing as follows: Float shoe (Ray Oil Tools Silver bullet) 2 jts. 40# L -80 casing - float collar(Halliburton Super Seal) 1 jt 40# L -80 casing & 1 jt 36# J -55 casing to 159' ( first 4 connections made up w/ BakerLoc - filled pipe & checked floats) 33 jts 36# J -55 casing & 3 jts 40# L -80 casing to 1650' (40 jts total in hole) Installed Bowspring centrallizers on jts.1 -13 & 1 bowspring cent. every other jtf / #15to #39 07:15 07:30 0.25 SURFAC CASING CIRC P 1,650.0 1,650.0 Establish circulation & circ btms up - staging pup up to 6 bbls /min @ 380 psi - PUwt125 SOwt110 07:30 10:00 2.50 SURFAC CASING RNCS P 1,650.0 2,989.0 Cont. to run 9 5/8' 40# L -80 casing f/ 1650' to 2950' (72 jts total in hole) PU landing jt & FMC fluted mandral hanger - Landed casing on landing ring w/ shoe @ 2989' & Float collar @ 2911' PU wt. 160 SO wt 125 Installed 1 bowspring centralizer every other jt f/ # 41 to # 69 10:00 10:45 0.75 SURFAC CEMENT RURD P 2,989.0 2,989.0 Rig down fill up tool & casing equipment - RU cement head & lines Latest BOP Test Data Date - AIF Comment - ,.. Page 1/3 Report Printed: 2/20/2012 NN Security Level: AK Development Daily Drilling Report i �i,,1 Y q6,lll CD3 -128 ° d j .�'u� r 9' ��' onocol�ls Report Number: 6 Rig: DOYON 19 Report Date: 4/14/2011 Time Log Start End Dur Time - Depth Start Depth End ' lime Time if (hrs) P hase ' _ Op Code " Activity Code P -T -x 1, Trbl Code' Trbl Class, (ftKS), ,' (ftKB),j Operation 10:45 12:30 1.75 SURFAC CEMENT CIRC P 2,989.0 2,989.0 Establish circulation & stage pump up to 6 bbls /min @ 430 psi - circ & condition hole & mud for cement job - final pressure 6 bbls /min @ 300 psi - Mud - 10.0 ppg / YP 19 / PV 18 / Gels 10 sec. 6 -10 min. 11 - PUwt160 SO wt. 142 12:30 12:45 0.25 SURFAC CEMENT SFTY P 2,989.0 2,989.0 Held pre job meeting w/ crew on cement job 12:45 15:30 2.75 SURFAC CEMENT CMNT P 2,989.0 2,989.0 Cemented 9 5/8" casing as follows: Pumped 70 bbls 10.0 ppg mud w/ nut plug & 35 bbls biozan water w/ nut plug for marker w/ rig pumps - Switched over to Dowell - Pumped 3 bbls water- Tested lines to 3270 psi - Aligned valves on cement head to drop bottom plug - Dropped bottom plug w/ 50 bbls 10.5 ppg MudPush @ 4.7 bbls /min @ 150 psi - Mixed & pumped lead slurry (AS Crete) @ 11.0 ppg - pumped 290 bbls and observed nut plug marker @ shakers - pumped down surge can - 300 bbls total lead pumped (822 sks) - Switched over to tail slurry ( Class G w/ 0.2% D046, 0.3% D065, & 1% S001) & pumped 48 bbls (231 sks) @ 15.8 ppg - Dropped top plug w/ 20 bbls water f/ Dowell - Switched over to rig pumps & dispalced cement w/ 202.3 bbls 10.0 ppg LSND mud @ 6 bbls /min @ 700 psi - Slowed pumps to 3.5 bbls /min for last 12.3 bbls @ 550 psi - bumped plug w/ 1120 psi - CIP @ 1530 hrs - Checked floats OK Full circulation & reciprocation throughout job - 38 bbls 11.0 ppg cement returns to surface 15:30 17:00 1.50 SURFAC CEMENT RURD P 2,989.0 2,989.0 PJSM. RD cement head & lines. Clear floor. LD landing jt. 17:00 18:00 1.00 SURFAC WHDBOP RURD P 2,989.0 2,989.0 ND riser and bell nipple. 18:00 21:30 3.50 SURFAC WHDBOP NUND P 2,989.0 2,989.0 PJSM. NU FMC wellhead and orient same. Test metal -to -metal seal to 1000 psi for 10 min - OK. NU BOPE. 21:30 22:15 0.75 SURFAC DRILL RURD P 2,989.0 2,989.0 Install mousehole. PU bails and elevators. 22:15 00:00 1.75 SURFAC DRILL PULD P 2,989.0 2,989.0 LD 2 stands 5" HWDP from derrick. Start picking up 5" DPand MU stands via mousehole for 8 3/4" hole section. Mud Check Data = ,,: 7. _ YE'CaIo el C . Gel -Get (1om) = Get (3O T1) . . t THP €i t, genslliy Tem S4 lkts p ` Corr; Type D (ftKB) Dens (wig*) a ds "(slgt). PV C alc(cp)1 ( f1l O ) 1b91O ) ° R ibi iOOft t (tbfJW MBT 0 l) (mLFSO niin) pry =° (F) (°1 ; ' ' '', Spud Mud 2,999.0 9.80 56 14.0 19.0 4.0 12.0 18.000 25.0 8.5 58.0 tnlection Flutcf , Flow Saui'ce From tease (bbl) Destinatian Meador - Manifest Number k Nate £„ Diesel 20.0 CD3 -106 Freeze protect Page 2/3 Report Printed: 2/20 /2012 Ir, Security Level: AK Development M i1 Daily Drilling Report CD3 -128 Report Number: 6 ConocoPttillips Rig: DOYON 19 Report Date: 4/14/2011 Injection Fluid ;Fluid Source From Lease (bbl) Destination Vendor Manifest Number Note . . Drilling Mud WBM CD3 -128 1039.0 CD3 -106 Drilling Mud WBM CD3 -128 368.0 CD3 -106 Cmt contaminated mud Fresh Water 20.0 CD3 -106 Water spacer Welitrores - Wellbore Name Wellbore API /UWI CD3 -128 501032063800 Section Size (in) , -- Act Top (ftKB) = Act Btm_(ftKB) - Start Date End Date COND1 19 36.8 114.0 4/1/2011 4/2/2011 SURFAC 12 1/4 114.0 2,999.0 4/11/2011 4/13/2011 INTRM1 8 3/4 2,999.0 13,020.0 4/16/2011 4/22/2011 Casing Strings String OD String Wt Casing Description Run Date tin} (lbs/ft) String Grade Set Depth (ftKB) -_ Comment SURFACE 4/14/2011 9 5/8 36.00 J -55 2,989.0 Ran 9 5/8" 40# L -80 & 9 5/8' 36# J -55 casing as follows: Float shoe (Ray Oil Tools Silver bullet) 2 jts. 40# L -80 casing - float collar(Halliburton Super Seal) 1 jt 40# L -80 casing & 1 jt 36# J -55 casing to 159' ( first 4 connections made up w/ BakerLoc - filled pipe & checked floats) 33 jts 36# J -55 casing & 3 jts 40# L -80 casing to 1650' (40 jts total in hole) Installed Bowspring centrallizers on jts.1 -13 & 1 bowspring cent. every other jt f/ # 15 to # 39 Establish circulation & circ btms up - staging pup up to 6 bbls /min @ 380 psi - PU wt 125 SO wt 110 Cont. to run 9 5/8' 40# L -80 casing f/ 1650' to 2950' (72 jts total in hole) PU landing jt & FMC fluted mandral hanger - Landed casing on landing ring w/ shoe @ 2989' & Float collar @ 2911' PU wt. 160 SO wt 125 Installed 1 bowspring centralizer every other jt f/ # 41 to # 69 Cement Surface Casing Cement - Started @ 4/14/2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3 -128 SURFACE, 2,989.0ftKB Got 38 bbls cement back to surface. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 38.6 2,989.0 4 550.0 ° Density tbt - t Yield ft' /sack Est To - ftKB Eat, ti n- (ftKB) Fluid COS* Amount;(sacks) v (bbl) ; ' � ( sat) t ) ` ' p Es 9 ( ) Lead Cement G 822 300.0 11.00 2.05 38.6 2,489.0 Tail Cement G 231 48.0 15.80 1.16 2,489.0 2,989.0 II Page 3/3 Report Printed: 2/20 /2012 . , PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD3-128 I Rig: Doyon 19 Date: I 4/16/2011 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: D. Mickey / D. Maskell Pump used: #2 Mud Pump ■ Strokes 0J0.09 Bbls/Strk '..":::: 0.8 Bbl/min ■ Type of Test: Casing Shoe Test LOT/FIT ■ Pumping down annulus and DP. ■ - - Casing Test Pressure Integrity Test Hole Size: 12-1/4" v Casing Shoe Depth Hole Depth Pumping Shut-in ' Pumping Shut-in RKB-CHF: 36.0IFt 2,989 I Ft-MDI 2,452IFt-TVD_ _ 3,019IFt-MD I 2,465IFt-TVD Strks psi Min psi Strks psi Min psi Casino Size and Description: 9-5/8 40#/Ft L-80 BTC v 0 0 0 ;•2500 :;:;:;:;:;:;1::;;:;:::::::;60; 0 ;::::::::790 Cask_ Jg"rest Pressure InteoritvTest 2 50 1 :2500: ::::::::::::2::::::::::::90; 0.25 :::::::20 Mud Weight: 9.7 ppg Mud Weight: 9.7 ppg - '.: ':':•I50 2 ::2500 ."::::::::::3:::::430 0.5:580 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 36.0 Lb/100 Ft2 :;- - .'..'6 .:::"400 3 ::2500 M3 ::::::::200: 1 7:::550 Test Pressure: 2,500 psi Rotating Weight: Lbs .':'' „ 8 .. 650 4 ':2500 =1 ;:;:;:::300 1.5 ;:;:;:;:;535 Rotating Weight: Lbs Blocks/Top Drive Weight: 75 000 Lbs '::::, 10 , „900 5 ::2500 :::::::::::;6; ;::::::::340 2 :;:;:::::: 530 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg ::::::::::;1000 6 ; :2500 ::::::::::::7: H440 2.5 ::":::":;520 Estimates for Test: 2.4 bbls Estimates for Test: 1058 psi 1 bbls ::::::::14: :1125 7 ":2500 :::':":':';8::":":":"500: 3 :::::':':520 • V V lli ' :127:5 8 E'2500 :::;:;:::;:;9 ; : ; :;:;:560 3.5 : ::: : :::;520 EMW = Leak-off Pressure + Mud Weight = 790 + PIT 15 Second :::::::18 1400 9 : :2500 :::::::::::,0 ::::::::610 4 ::::::::;515 9.7 0.052 x TVD 0.052 x 2452 Shut-in Pressure, psi :::::20 ::1550 10 ::2500 •:::::::::, 1 :::::::570 4.5 ,...,,,..:,.. .,......„..: EMW at 2989. Ft-MD (2452 Ft-TVD) = 15.9 ppg 620 ;:;:;:;:22 ;:;1750 15 ::2500 .. ' . Z :;::,.00 5 .:*::::::515 3000 c Lost 0 psi during test, held — ''":::24 :::1000 20 :;2500 ;:;:;::::13:::::::::7-9 5.5 :, ::::::510 , 100% of test pressure. — :.ze, :' 2100 25 ::2500 ":::: t ::790 6 ::::::51Q .4m1...1 1 Yr 1 1 I I 1 :i::1;i20, ; 2300 30 ":2500 IMO ::::::::: :90 6.5 2500 ' '' : " .41 " 441 ' " • ' ''' '' 30 ::2500 ::::::::::: ,, ":::::::700: 7 ;:;510 ------ :::::,' , : : : .:;:,,,,,,, "'" ■■11=111MIN■1=111 :::::.','-':',- .:::::'::::::, ;::::;: .,.. ;:.„..: 790 7.5 :":;';'"510 IMM■NIMMIIMNIIII■MIIIIII :::::::'::::: ::,::::::::::: ------ :::::;-;:;:',::: :::;::';';'''' • 2000 ■■■MMIUMM■ :;:;:;:::;:::;! ::i::::: IMENN 8 . 5 ,. ::: W . ■•■■■■•■ ::;:; ; ::;:::: :. cC . ■■••••■■■• ::::;:::::::::: ::::::::::: ::::;:;:;:;.;.,. 9 :;510 m INNII■■■=imm ....::::.::,.„.„,.,. ... O 1500 A 11=INNIIIMINIIIM■11111011 : : :::::':: : :::::;:;: :::--i:':::: 9.5 ::::::510 , u) ■■Immissm■■1 , - : ..:.: .::::::::::::: w ■■■■•••■ '::::.::: : ... ' ::::::::::: ";;;;;;;;;;;:::: 10::::;:;;"510 cc ., 111111111■■■•••1111= 111•11111M1111111■■■1111= 1000 . MIIIMIIIIIMI■■IIIIIIII ::::::::;;;;;;; ;;;;;;;;;;„; • 11111111111111•1■MIII■1111= .:: .:. „ ::.... ." . ----- i:;;;;;;;:;: ii'':::::- i M11111111111111■■1101111 • .. ." .: : : . .: :::::::•••• 500 i r"" - :1_ ■•11111111111=1■MEN : : : :: ::":::: : ::::::::::: --- --- 0 •11111111111111111•1■111■=1111■1 ;:;:;:;:;:;:;:: ::: : : : : : ■•11•111■11■MNIMMII ":,',':'''''::: '-'":: ''''' .„, ,„, ,,. ■■•11111•11•1111M■•1111111 ''.: : ;;;:;: : :;:,:;-:.::: ■■■•111•111■■ „ - . :."" : ' ''''''" : . 0 1 2 3 4 0 5 10 15 20 25 30 ;:;; Barrels Shut-In time, Minutes Volume Volume Volume Volume Back Pumped 6 ".trm'CASING TEST —M— LEAK-OFF TEST 0 PIT Point Pumped Bled Bled Back Comments: Note: surface casing 40 # L-80 & 36# J-55 Casing Detail Well: CO3-128 7" 26# L-60 EC mod Date: 412412011 Conoco Phillips Rig: Doyon 19 Alaska, Inc, Depth Jt Number Joints Well Equipment Description and Comments 11101 Length Tops Page 1 1,1! Top of String or Top of Flange RKB to Casing Flange (LLDS = 33.60') 33.60 , 11111091111111111111likii FMC Gen V Casing Hanger (7" Pup = 2.23') 2.62 33.60 Jts 136 to 302 167 Jts 7" 26# L-80 BTC-M Casing 7194.12 36.22 HaHiburton ES Cementer 2.43 7230.34 Jts 4 to 135 132 Jts 7" 26# L BTC Casing 5648.05 7232.77 HES Baffle Collar 1.01 12880.82 Jts 3 to 3 1 Jts 7" 26# L-80 BTC-M Casing 40.96 12881.83 HES Super Seal H Float Collar with Baffle Adapter 1.00 12922.79 Jts 1 to 2 2 Jts 7" 26# L-80 BTC-M Casing 83.88 12923.79 Ray Oil Tools Float Shoe 2.12 13007.67 13009.79 13009.79 13009.79 13009.79 8 3/4" OH TD = 13,020' MD 6983 ' TVD. 13009.79 7" Shoe =13,009.79 MD 6982 ' TVD. 13009.79 13009.79 Centralizers - 163 Hydroform - 15 straight blades 13009.79 Straight blade centralizer on jt. # 1 13009.79 1 hydroform centralizer per jt from # 2 to # 163 13009.79 Straight blade centralizers on jts 233,234 &,235 13009.79 Straight blade centralizers on every other jt f/ 237 to 255 13009.79 Straight blade centralizers on jts 298 & 300 13009.79 13009.79 13009.79 13009.79 Qannik formation top 6490 Base 6708 13009.79 Top of Kuparuk "C" - 12,481 ' MD 6827 ' TVD 13009.79 Top of Nechelik - 12,913' MD 6965 ' TVD 13009.79 13009.79 13009.79 13009.79 335 joints in pipe shed 13009.79 302 joints to run - last 33 joints stay out 13009.79 13009.79 Remarks: Up Wt 345 Dn Wt 155 Block Wt 75 K Supervisors: D. Mickey / J. Browning l ljl I -, I �pl ll , 1 4 . , z _ n' ,r1 Cement Detail Report II 0IVl 111111 °'''Id'',' ' 1'I111111 CD3 - 128 Ca'nocoPhillips 'IPi , u String: Intermediate Casing Cement 9 9 Cement Details .h Job: DRILLING ORIGINAL, 4/9/2011 17:00 Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/25/2011 21:30 4/26/2011 02:50 CD3 -128 Comment Cement Stages ,r 4E I Stage.## 1 Or - - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Primary 11,977.0 13,020.0 Yes 0.0 Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 5 530.0 530.0 Yes 16.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 12,880.0 Drill Bit 12,880.0 Comment t e'rrlent °Fluids & Additives -, ., 4 ... Fluid _ ' ` . - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 11,977.0 13,020.0 215 G 46.5 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 115.3 7.50 Additives Additive Type Concentration Conc Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Stage #;;2;;;V A Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Qannik Primary 5,990.0 7,232.0 Yes 0.0 Yes No Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 5 5 320.0 320.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement F luids &^ Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 6,990.0 7,232.0 225 G 46.5 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 95.7 4.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.3 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 %BWOC Page 1/1 Report Printed: 2/20/2012 ii Security Level: AK Developmertr ° Gill + gi;;,I " jqu'P,'GU'' Daily Drilling Report wei CD3 -128 g idlllVViui ,I" ccattlltps Report Number: 16 Rig: DOYON 19 Report Date: 4/24/2011 AFE Type " "N�etwork/lD # «TOtatiAFE +SuR 'p 10302125 8,450, 000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 128 Development FIORD KUPARUK 13.70 16.0 0.00 13,020.0 13,020.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,851.08 536,364.83 179,769.08 3,585,708.83 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/9/2011 4/11/2011 28.80 18.20 10.60 4/27/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,989.0ftKB Ops and Depth @ Morning Report 24hr Forecast Running 7" Casing @ 9051' Run & Cement 7" Caisng Last 24hr Summary Continue to POOH f/ 4,492' to 2,997' MD; Wiped Tight Spots - OWFF (Static) Pump Viscosified Sweep - OWFF (Static) - POOH f/ 2,997' to 206' MD - L/D BHA #4 - Flush BOPE Stack - Slip and Cut Drill Line - Change Upper Rams t/ 7" Solid Body - Test Upper Rams t/ 250/3500 Psi - R/U and Run 7" Casing t/ 5,131' MD; Stopping to Circulate @ 170', 2,971' and 5,131' MD General Remarks Weather Head Count No Spills, No Accidents, No Injuries -11°, WC -26 °, Overcast, Wind SW @ 7 Mph 45.0 Supervisor'„ Tate , Don Mickey, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Time Lag Start End: Our s_ Time" PROrt= Start Depth End Time Time- (hrs) - = Phase Op Code "o Activity Code P-T -x Trtal Code Trbl Class. " (ftKB) (fitKt3) Operatiott 00:00 00:45 0.75 INTRM1 DRILL TRIP P 4,492.0 2,997.0 POOH f/ 4,492' to 2,997' MD - P/U 135, S/O 124 Wiped Through Tight Spots: 4,390', 4,295', 4,216' and 3,960' MD 00:45 01:45 1.00 INTRM1 DRILL CIRC P 2,997.0 2,997.0 Stage Pumps Up t/ 575 GPM w/ 1860 Psi and Rotated 40 -60 RPM - Pump Viscosified Nut Plug Sweep Around; Moderate Increase in Cuttings Size and Quantity 01:45 02:00 0.25 INTRM1 DRILL OWFF P 2,997.0 2,997.0 Blow Down the Top Drive and Monitor the Well (Static) 02:00 03:15 1.25 INTRM1 CASING PULD P 206.0 176.0 LD 2 NM flex DC's - PJSM on RA sources - Remove RA sources f/ MWD - LD NM flex DC to 176' 03:15 04:15 1.00 INTRM1 CASING OTHR P 176.0 176.0 Plug in & down load MWD data 04:15 05:30 1.25 INTRM1 CASING PULD P 176.0 0.0 Finish laying down BHA 05:30 06:00 0.50 INTRM1 CASING OTHR P 0.0 0.0 Clean up rig floor & remove BHA tools from rig floor 06:00 06:30 0.50 INTRM1 CASING OTHR P 0.0 0.0 MU stack washer & flush BOP stack @ 10 bbls /min @ 160 psi - function rams - LD stack washer 06:30 08:00 1.50 INTRM1 CASING SLPC P 0.0 0.0 PJSM - Slip & cut drill line - service TD 08:00 09:00 1.00 INTRM1 WHDBOP OTHR P 0.0 0.0 Changed top pipe rams f/ VBR to 7" solid body 09:00 11:00 2.00 INTRM1 WHDBOP PRTS P 0.0 0.0 Pull wear bushing - set test plug - RU test equipment - Test upper pipe rasm to 250 & 3500 psi - RD tes equipment - Pull test plug set thin wall wear bushing 11:00 12:15 1.25 COMPZN CASING RURD P 0.0 0.0 RU to run 7' casing 12:15 12:30 0.25 COMPZN CASING SFTY P 0.0 0.0 PJSM on running 7" casing Latest BOP Test Data Y, ' Date Comme ',i . 4/15/2011 Witness of test waived by AOGCC Rep Bob Noble. Page 1/2 Report Printed: 2/20/2012 hlli 1 Security Level: AK Development , Daily Drilling Report t'° CD3 -128 CcncacctPt�illiPs Report Number: 16 Rig: DOYON 19 Report Date: 4/24/2011 T ime L.ogf Start End ' Dyr Tame - _ Depth Start Depth End Time = =,Time (his) 'Phase; Op Code = Activity Code P T X _ _' Trial Code TM :Glass. (ff<B) " (flK8) Operatics 12:30 13:00 0.50 COMPZN CASING RNCS P 0.0 170.0 Ran 7" 26# L -80 BTC -mod casing as follows: Float shoe(Ray Oil Tools silver bullet) 2 jts casing - float collar (Halliburton Super Seal II w/ baffle adaptor installed) 1 jt casing - Baffle collar (Halliburton) 1 jt casing (first 4 jts made up w/ BakerLoc - filled pipe & checked floats) to 170' 13:00 16:15 3.25 COMPZN CASING RNCS P 170.0 2,971.0 Continue to Run 7" Casing f/ 170' to 2,971' MD (69 Jts in Hole) P/U 130, S/0 124 16:15 17:15 1.00 COMPZN CASING CIRC P 2,971.0 2,971.0 Stage Pumps up t/ 5 BPM @ 270 Psi and Circulate Casing Volume 17:15 20:15 3.00 COMPZN CASING RNCS P 2,971.0 5,131.0 Continue to Run 7" Casing f/ 2,971' to 5,131' MD (120 Jts of 302 In Hole) P/U 165, S/0 130 20:15 21:00 0.75 COMPZN CASING CIRC P 5,131.0 5,131.0 Stage Rate Up t/ 5 BPM @ 370 Psi and CBU 21:00 00:00 3.00 COMPZN CASING RNCS P 5,131.0 5,561.0 Continue to Run 7" Casing f/ 5,131' to 5,561' MD (130 Jts of 302 In Hole) P/U 175, S/O 132 /Mud Check Data YP'Calc Gel (10s) " Gel (10m) Gel(30m) HTHP Filt . Density Temp Solids, Gorr. Type Depth (ftKB) _Dens (ib/gal). , Vis (s /qt) PV Calc (cp) _` ([bf /100fF) (Ibf /100ft'j (1iar /100fF) (Ibf /1,00ft') ', MBT (Ibibbi) (mU30min} pH (`F) ( ) Glydril 13,020.0 11.50 44 16.0 21.0 7.0 10.0 13.000 17.5 6.4 9.4 80.0 Injection Fluid Fluid Source FromLease. (bbl) Destination Vendor ! Manifest Number Note No injection Wellbores_ Welibore Name Welibore API /UWI CD3 -128 501032063800 Section Site (in) +` Act Top, (ftKB) Act Btm (ftKB) Start', Date ` End, Date COND1 19 36.8 114.0 4/1/2011 4/2/2011 SURFAC 12 1/4 114.0 2,999.0 4/11/2011 4/13/2011 INTRM1 8 3/4 2,999.0 13,020.0 4/16/2011 4/22/2011 Survey Data- . MD (ftK B) , -_-- Ittcl ( °) A (°) ', i TVD (ftKB) VS (ft) NS (ft}' EW (ft} DCS' (°100ff) ( ' 13,020.00 81.92 181.50 6,983.21 - 861.93 - 3,167.48 - 8,832.20 0.00 Page 2/2 Report Printed: 2/20/2012 l i '. � "" ''� Illu Security Level: AK Development 1ii�l�iii Daily Drilling Report �1Vlµ'IiIIJ """ ii.i c 0 ,1 1 I I a6 0 CD3 -128 C+noaPtti)lips p Report Number: 17 Rig: DOYON 19 Report Date: 4/25/2011 _- AFE Type ' i Networ ilD # _ -_ _ ,Total AFE +Sup. , ,: 10302125 8,450,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -128 Development FIORD KUPARUK 14.70 17.0 0.00 13,020.0 13,020.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,276.41 540,641.24 445,364.41 4,031,073.24 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/9/2011 4/11/2011 28.80 18.20 10.60 4/27/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) PRODUCTION, 13,009.0ftKB Ops and Depth ac Morning Report 24hr Forecast Prep to LD 5" DP Cement 2nd Stage - Set and Test Pack Off - L /D 5" DP Last 24hr Summary Continue to Run 7" Casing f/ 5,561' to 13,010' MD; Stopping to CBU @ 7,282', 9,440', and 11,594' MD - R/U Cement Head and Circulate and Condition Mud to Lower YP to < 20 and MW to 11.3 PPG - Cement Intermediate Casing Shoe (1st Stage) w/ 45.6 Bbls 15.8 PPG Class G Cement; ETOC 11,977 MD General Remarks Weather Head Count No Spills, No Accidents, No Injuries -9 °, WC -20 °, Clear, Wind SW @ 5 Mph 45.0 ` Supervisor :7:::, ° Title .,= Don Mickey, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor : time Log Start End Dur ° ° _ Time Depth Start Depth End Time Time+ (firs) 'Phase = Op Code ,Activity Code P -T -k' Trb tCode Trbl Class. (5K8)' -' ,'(5K8) Operation 00:00 02:15 2.25 COMPZN CASING RNCS P 5,561.0 7,287.0 Continue to Run 7" Casing f/ 5,561' to 7,287' MD (170 Jts of 302 In Hole) P/U 205, S/O 138 02:15 03:30 1.25 COMPZN CASING CIRC P 7,287.0 7,282.0 Stage Rate Up to 5 BPM w/ 450 Psi and CBU 03:30 07:00 3.50 COMPZN CASING RNCS P 7,282.0 9,440.0 Continue to Run 7" Casing f/ 7,282' to 9440' ( 220 jts of 302 to run) PU wt. 247 SO wt 147 07:00 08:45 1.75 COMPZN CASING CIRC P 9,440.0 9,440.0 Stage pump up to 5 bbls /min @ 460 psi & circ btms up 08:45 12:00 3.25 COMPZN CASING RNCS P 9,440.0 11,594.0 Continue RIH w/ 7" 26# L -80 BTC -mod casing f/ 9440' to 11,594' (270 jts of 302 to run) PU wt. 290 SO wt - 155 12:00 14:00 2.00 COMPZN CASING CIRC P 11,594.0 11,594.0 Stage pump up to 5 bbls /min @ 540 psi - circ btms up + conditioning mud 14:00 17:00 3.00 COMPZN CASING RNCS P 11,594.0 13,010.0 Continue RIH w/ 7" 26# L -80 BTC mod casing f/ 11594' to 12973' (302 jts total in hole) PU FMC fluted mandral hnager & landing jt. - Landed casing on hanger in wellhead w/ shoe @ 13,009.79' - Fc @ 12,922.79' - Baffle collar @ 12,880.82' - Stage collar @ 7230.34' 17:00 17:30 0.50 COMPZN CEMENT RURD P 13,010.0 13,010.0 R/U Cement Head and Lines 17:30 21:30 4.00 COMPZN CEMENT CIRC P 13,010.0 13,010.0 Circulate and Condition Mud Until YP < 20; MW 11.3 PPG - SIMOPS: Hold PJSM for First Stage Cement Job 5 BPM @ 650 Psi Latest BOP Test Data Date yCommegt,- 4/15/2011 Witness of test waived by AOGCC Rep Bob Noble. Page 1/3 Report Printed: 2/20/2012 'I �� , Irylll , Security Level: AK Development rl�w�I Il ,lllu .';!!111:11 Daily Drilling Report ir �� i IgF M.'iLl i i1 11 ll 1,7j: i6di � i y l i l I lei CD3- 1 28 itlips hk Report Number: 17 Time Log Rig: DOYON 19 Report Date: 4/25/2011 Start End Dur , _ - Time ; ' Depth Start Depth End Time Time,, (hrs).;" Phase Op Activity Code P T -X Trbt Code Trbl Class. (ftKB) cItKB)'', ©peratign 21:30 22:30 1.00 COMPZN CEMENT CMNT P 13,010.0 13,010.0 Pump 1st Stage Cement as Follows: Pump 2 Bbls CW 100 - Pressure Test Surface Lines t/ 3700 Psi - Pump 30 Bbls 8.4 PPG CW 100 @ 4 BPM w/ 500 Psi - Pump 30 Bbls 12.5 PPG Mud Push @ 4.5 BPM w/ 550 Psi - Pump 45.6 BBIs 15.8 PPG Class G Cement w/ Additives - Pump 20 Bbls Water Behind Top Plug 22:30 00:00 1.50 COMPZN CEMENT DISP P 13,010.0 13,010.0 Begin Displacing Cement Fluid Train w/ 11.3 PPG Mud @ 5 BPM w/ 600 Psi - Slowed Pumps to 3 BPM w/ 530 Psi w/ 468 BBIs of Mud Pumped - Bumped Plug @ 474 Bbls - Held 1150 Psi f/ 5 Minutes - Checked Floats (Good) - CIP 0005 4/26/2011 Mud Check Dat ,, YP Catc _ Gel (105) Get(lOm)'',` Get (30m) I-tTHPFitt Density Tamp Solids;, Corr. Type Depth (ftKO) Dens (ibigal) -Vis (s /qt) PV Calc (cp) (Ibf /100fW)`= (Ibf /100ft=) (Ibf /100fta)', Obf 11,00K MABT (Ib/bbl) (mU30min) pH (°F):1011!1';' ( %) Glydril 13,020.0 11.30 45 16.0 20.0 7.0 10.0 11.000 18.0 6.4 9.1 78.0 Injecti Fluid :Rod Source From, Lease(bbi)_ Destination Vendor Manifest Number I Note Drilling Mud WBM CD3 -128 280.0 CD1 -19 ASRC 340538 Wellbores Wellbore Name Welibore API /UWI CD3 -128 501032063800 Section Size (in) Act''Top- (ftKB) Act Btm (ftKB) Start Date End Date COND1 19 36.8 114.0 4/1/2011 4/2/2011 SURFAC 12 1/4 114.0 2,999.0 4/11/2011 4/13/2011 INTRM1 8 3/4 2,999.0 13,020.0 4/16/2011 4/22/2011 Survey Data MD, (ftKB) tnct ( °). „' Azm ( °) s. TVD =(1tKB} us. (ft) NS (ft) Euu'(ft) DLS ( °1100ft) 13,020.00 81.92 181.50 6,983.21 - 861.93 - 3,167.48 - 8,832.20 0.00 Page 2/3 Report Printed: 2/20 /2012 �'rhtl Vlil N"� D°� Security Level: AK Development Ipj ' ' I1 Q Daily Drilling Report I If Ilp 61 p CD3-128 =if Report Number: 17 1ConocoPhillips Rig: DOYON 19 Report Date: 4/25/2011 Casing'Strings Stein 00 String Wt `Casing Description Run Date (in) (WAY - - String Grade Set Depth (ftKB)' Comment PRODUCTION 4/25/2011 7 26.00 L -80 13,009.0 Ran 7" 26# L -80 BTC -mod casing as follows: Float shoe(Ray Oil Tools silver bullet) 2 jts casing - float collar (Halliburton Super Seal II w/ baffle adaptor installed) 1 jt casing - Baffle collar ( Halliburton) 1 jt casing (first 4 jts made up w/ BakerLoc - filled pipe & checked floats) to 170' Continue to Run 7" Casing f/ 170' to 2,971' MD (69 Jts in Hole) P/U 130, S/0 124 Stage Pumps up t/ 5 BPM @ 270 Psi and Circulate Casing Volume Continue to Run 7" Casing f/ 2,971' to 5,131' MD (120 Jts of 302 In Hole) P/U 165, S/0 130 Stage Rate Up t/ 5 BPM @ 370 Psi and CBU Continue to Run 7" Casing f/ 5,131' to 5,561' MD (130 Jts of 302 In Hole) P/U 175, S/0 132 Continue to Run 7" Casing f/ 5,561' to 7,287' MD (170 Jts of 302 In Hole) P/U 205, S/O 138 Stage Rate Up to 5 BPM w/ 450 Psi and CBU Continue to Run 7" Casing f/ 7,282' to 9440' ( 220 jts of 302 to run) PU wt. 247 SO wt 147 - Stage pump up to 5 bbls /min @ 460 psi & circ btms up Continue RIH w/ 7" 26# L -80 BTC -mod casing f/ 9440' to 11,594' (270 jts of 302 to run) PU wt. 290 SO wt - 155 Stage pump up to 5 bbls /min @ 540 psi - circ btms up + conditioning mud Continue RIH w/ 7" 26# L -80 BTC mod casing f/ 11594' to 12973' (302 jts total in hole) PU FMC fluted mandral hnager & landing jt. - Landed casing on hanger in wellhead w/ shoe @ 13,009.79' - Fc @ 12,922.79' - Baffle collar @ 12,880.82' - Stage collar @ 7230.34' ;Cement Intermediate Casing Cement - Started @ 4/25/2011 Type Welibore Cemented String Cement Evaluation Results casing CD3 - 128 PRODUCTION, 13,009.0ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 11,977.0 13,020.0 3 530.0 Fluid Class Amo un t-fsacks) - -= V (bbt) Density (tb /gsl) Yield (ft'/sack) Est Top (ftKB) Wqi Est Btm (ftKB} Tail Cement G 215 46.5 15.80 1.16 11,977.0 13,020.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Qannik 5,990.0 7,232.0 5 320.0 Fluid:_ _ Class ( Amount (sacks) '- 'I V (bbt) ',', Density (Ib /gat) Yield (fe /sack) Est Top (ftKt3) I - _- -_ Est Btm (ftKB) Tail Cement G 225 46.5 15.80 1.16 6,990.0 7,232.0 Page 3/3 Report Printed: 2/20/2012 Security Level: AK Development Daily Drilling Report ill 4 r i i � 1111,1,0_001:11!-t.- ° �.. CD3 -128 Report Number: 18 Cot ocoPhillips Rig: DOYON 19 Report Date: 4/26/2011 _ AFE Type Networ JID # Total AFE +SUp . 10302125 8,450,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 128 Development FIORD KUPARUK 15.70 18.0 0.00 13,020.0 13,020.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 17,329.81 557,971.05 277,564.81 4,308,638.05 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/9/2011 4/11/2011 28.80 18.20 10.60 4/27/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) PRODUCTION, 13,009.0ftKB Ops and Depth i Morning Report 24hr Forecast RIH @ 1,850' MD (0530) P/U Clean Out BHA and Single In Hole - Clean Out Stage Collar - RIH and Displace Wellbore to Brine - POOH Last 24hr Summary Open HES Cementer - CBU Through Open Stage Collar - Cement Qannik w/ 46.5 Bbls Class G Cement w/ Additives (CIP @ 0255) - Install and Test 7" Pack Off t/ 5,000 Psi f/ 10 minutes - UD 5" DP - Change Upper Rams and Test Upper, Lower and Annular w/ 3 and 4" Test Joints - Continue to UD 5" DP General Remarks Weather Head Count No Spills, No Accidents, No Injuries - Polar Bear Sighted w/i 1 Mile of Ice Road; Road Closed 3 °, WC -12 °, Clear, Wind NE @ 9 Mph 45.0 to Traffic Until Further Notice Supervisor Title. Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Time Log Start Ends' Dur Time Depth Start Depth Egad Time Time (hrs)" phase Op Code "' Activity Code=ii P - T - X Trbl' Code Trbl Class. (ftKB) (fKS)'! Operation 00:00 00:30 0.50 COMPZN CEMENT RURD P 13,010.0 13,010.0 Pressusre Up to 3540 Psi to Open Stage Collar - R/U for Second Stage - Load Closing Plug 00:30 01:15 0.75 COMPZN CEMENT CIRC P 13,010.0 13,010.0 CBU Through Open HES Cementer @ 7 BPM w/ 450 Psi 01:15 02:15 1.00 COMPZN CEMENT CMNT P 13,010.0 13,010.0 PJSM on Second Stage Cementing - Cement Second Stage as Follows: Pump 31.8 Bbls CW 100 @ 3.5 BPM w/ 280 Psi, Pump 27.3 Bbls 12.5 PPG Mud Push @ 4 BPM w/ 330 Psi, Pump 46.5 Bbls 15.8 PPG Class G Cement w/ Additives @ 5.3 BPM w/ 300 Psi, Drop Closing Plug, Pump 20 Bbls Wash Water Behind Plug 02:15 03:00 0.75 COMPZN CEMENT DISP P 13,010.0 13,010.0 Displace Cement w/ 259 Bbls of 11.3 PPG Mud @ 7 BPM w/ 390 to 520 Psi; Slowed Rate t/ 4 BPM w/ 320 Psi w/ 245 Bbls Pumped - Observed Plug Land - Increased Pressure to 2000 Psi to Close Stage Collar - Release Pressure - Verify Stage Collar Closure - OWFF (Static) - CIP @ 0255 03:00 06:00 3.00 COMPZN CEMENT RURD P 13,010.0 13,010.0 R/D Cementing Equipment - UD Landing Joint - Change Bales & Elevators - Install Wear Ring - SIMOPS: Install Pack Off in Well Head and Test t/ 5,000 Psi f/ 10 Minutes 06:00 12:45 6.75 COMPZN DRILL PULD P 0.0 0.0 UD 5" DP Via the Mouse Hole 12:45 13:45 1.00 COMPZN WHDBOP SEQP P 0.0 0.0 Hold PJSM and Change Upper Rams t/ 3'/i' by 6" Variable Rams 13:45 14:15 0.50 COMPZN RIGMNT SVRG P 0.0 0.0 Service Rig 14:15 15:00 0.75 COMPZN RIGMNT RGRP T Rig Top Drive 0.0 0.0 Work on Top Drive Brushes 15:00 17:30 2.50 COMPZN WHDBOP BOPE P 0.0 0.0 Test Upper /Lower Rams and Annular w/ 3'/2' and 4 Test Joint t/ 250/3500 Psi and 250/2500 Psi Latest BOP Test Data pater Comment.';, 4/15/2011 Witness of test waived by AOGCC Rep Bob Noble. Page 1/2 Report Printed: 2/20/2012 T Security Level: AK Development 9'; ." `. ° "I ' 1 Daily Drilling Report i 11 r I II 1 il� 4lki, . I :.' 't CD3 -128 t- -,,,, �l,1 t ih1 = Report Number: 18 Con coPhittips . 011 Rig: DOYON 19 Report Date: 4/26/2011 Time Log Start End Pur Tame : Depth Start Depth End ` Time Time • (hrs) Phase', tip C ode Activity C ode P T X = Trbi Code Trbt Ciass. '(ftKB) ''s (ftKB) Operation 17:30 00:00 6.50 COMPZN DRILL PULD P 0.0 0.0 Continue to L/D 5" DP via the Mouse Hole Mud Check Data = _ _ YP Catc Gei (10s) Gel {'10m) _Gel (30m) HTHP Filt Density Temp ,_ Soiids, Corr. Type Depth. (ftKB) Dens (16/gal) Vis (s /qt) PV Calc (cp) (Ibfi1 OQft') }` (IbfI100ftW) (Ibf /100ft _ (lbf /100ft'} _ = MBT (!b /bbl) +(m0P,©min) pH ( °F) ( %) _ Glydril 13,020.0 11.30 42 16.0 17.0 7.0 10.0 11.000 18.0 6.4 9.2 60.0 Glydril 13,020.0 11.30 42 16.0 17.0 7.0 10.0 11.000 18.0 6.4 9.2 63.0 Injection Fluid . ", Fluid : =_: Source From Lease (bbl) Destination Vendor Manifest Number Note Diesel CD3 -128 60.0 CD3 -128 Freeze Protect Other CD3 -128 12.5 CD3 -128 LOT Water CD3 -128 300.0 CD3 -128 Flush Wellbores Wellbore Name Well bore API /UWI CD3 -128 501032063800 Section- - -_ ': : Size (in) Act Top (ftKB) Act Btm- (ftK,B) Start Date End, Date COND1 19 36.8 114.0 4/1/2011 4/2/2011 SURFAC 12 1/4 114.0 2,999.0 4/11/2011 4/13/2011 I NTRM1 8 3/4 2,999.0 13,020.0 4/16/2011 4/22/2011 Surve Data ,_ MD (ftK6 }' ; -' tnci( °) Azm ( °) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS ( °t100ft), 13,020.00 81.92 181.50 6,983.21 - 861.93 - 3,167.48 - 8,832.20 0.00 Page 2/2 Report Printed: 2/20/2012 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -128 Rig: Doyan 19 Date: 4126/20/1 Volume Input I Pump Rate: Drilling Supervisor: I D. Burley /J. Browning , IPump used: Cement Unit ■ Barrels Bbls /Strk a8 Bbl /min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down USE LIST ■ Casing Test Pressure Integrity Test Hole Size: 8 - 3/4" V Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 33.6IFt 2 -MDR 2,452IFt -TVD 4,640IFt -MD I 3,195IFt-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 -5/8" 40 # /Ft L -80 BTC V 0 : ::!:!::.: ,:: 0 !0 0 : ;::::500 Changes for Annular Adequacy Test Pressure IntegritvTest 1 ., !; ;!:!;:;0;S; ;:;.;;:;;7:0 0.25 : : : ::::445 outer casing shoe test results in comments Mud Weight:I 11.2 ppg 2 :,:; ' : :::4::::?i:20: 0.5 :;:;:;:;:438 Description references outer casing string. Inner casing OD: 7.0 In 3 ' :: ;:;:'::::1;5 1 :;:;:;:::425 • ize is that drilled below outer casing. 4 ::2 ;;;240 1.5 418 timated TOC for Hole Depth. 5 i ; : ::: ;:::;::2:5 , ;:;;;;;;301. 2 ::;:;::;;41;1 Enter inner casing OD at right Desired PIT EMW: 15.0 ppg 6 -3 ;; ; 318 2.5 ::;::;;;;405 Estimates for Test: 485 psi 0.2 bbls ! 7 ;; ;:; :::::::'15 5 : ' - 310 3::::::::402 V V 8 : ::: ' : : : : : : : : : ::: : 3.5 :: :: : EMW = Leak -off Pressure + Mud Weight = 574 PIT 15 Second 9 ; ; ;: :':;:4.5:::::::::383: 4 ;:;:;:;: + 11.2 0.052 x TVD 0.052 x 2452 Shut -in Pressure, psi 10 5 ::::::::42'1: 4.5 ::::::: 393 , I , II ;;. f .A A 1 A EMW at 2989 Ft -MD (2452 Ft -TVD) = 15.7 445 15 ; : ; 5:5 :::::::406 5 : 392 1000 – – 20 :::::::::::::6':::;:;'485' 5.5 :::::::::389 ----- 25 : ; 6.5 ::=;:;:512: 6 387 ------- 30 : ; ;; 5: 6.5 :384 7.5 ::::::::57:4: 7 ::::::::384 ---_- 8 - ::::::5 7.5 ;::;::`:::382 w ---- � 542 8.5 381 • r 9:5 : 9 :::::::;::380, N 500 --- � 10 - .. -:.:503: 9.5 :::::::::379 IIKIMMIIIIIIIIIN l;. ;10:5::: 10 : 378 a �', ,: ...... :H::::11:::::::::506 45 ::: 459 ELM ----- 12, ':::::::5(34' IrAll ELM r o . 0 2 4 s 8 10 12 14 0 5 10 15 20 25 30 Volume Volume Volume Volume Barrels Shut -I n time, Mi nutes ttim•CASINGTEST ••••E—LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls Bbls 12.5 Bbls ; ;: ;iBbls Comments: 9 5/8 ", 40# L -80 & 36# J -55 Surface Casing LOT + 15.9 ppg CD3 -199 Information CD3 -199 9 -5/8" Surface Casing Well: CD3 - 199 9 40 Yof L$ T C - m Casino Date: 2/10/2011 4Q�QCUI`I l���ip� Rig: Don Rig 141 Alaska, Inc. Depth JtNumber Joints Well Equipment Description and Comments Length Tops • Page 1 2: R fi t p lri r� r�r� 9a5 !? :C = 111 : 11 iiiiiiiiir '!!i!!!;!;!!!! /!!iii" !' RKB to Top of Landing Ring 26 . 53 Iliil '!!!!;!!!!!!!' !I!!'s.!!!I'!!II!!II!!II!!,;1i. FMC 9 5/8" Casing Hanger .21 26.53 9 -5/8" Pup in the hanger pin x pin 2.15 26.74 Jts 3 to 65 63 Jts 9 5/8 ", 40.0 #, L - 80, BTC Casing 2555.18 28.89 HS 9 5/8" Sure Seal II Float Collar 1.21 2584.07 Jts 1 to 2 2 Jts 9 5/8 ", 40.0, L -80, BTC Casing 75.36 2585.28 Ray Oil Tools 9 5/8" Silver Bullet Float Shoe 2.24 2660.64 Shoe depth 2662.88 2662.88 Baker Lock 1st 3 joints and pin on 4th joint 2662.88 2662.88 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 2662.88 1 Bowspring Centralizer on stop collar 10' below the box of joint # 2 2662.88 2662.88 Bowspring centralizers on joints # 4 - #13. Then run Bowspring 2662.88 centralizer every other joint #15 to #63. 2662.88 2662.88 Centralizer placement highlighted in yellow on tally sheet. 2662.88 39 total centralizers, 2 stop rings 2662.88 2662.88 5 Joints of 9 - 5/8" casing remain in shed 2662.88 2662.88 TD © 2673' MD ( 2464.67' TVD) 2662.88 Shoe @ 2662.88' MD ( 2457.01' TVD) 2662.88 Rat hole 10.12'. 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 2662.88 Remarks: Drifted w/ 8.775" teflon drift Up Wt 125 K Used Jet Lube Run -N -Seal dope. Dn Wt 112 K Torqued to 10,000 Ft lbs of torque Block Wt 35 K Supervisors :Granville Rizek/ Elmo Cecchetti il i l ii�; I �P I;i', I IIq hl'hII ail lllllli41l Cement Detail Report I I II�I I i �.. 'i;�ll 'llhl li Il i CD3 -199 i „,r II C coPhil ips String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/7/2011 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/10/2011 21:25 2/10/2011 23:59 CD3 - 199 Comment Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker (5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k Ibs and S/O 112k lbs. Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water /sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Dowell kick out top plug w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls /stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k Ibs to 85k lbs. Landed on hanger at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. Cement Stages Stage # 1l= Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Cement surface casing 26.5 2,673.0 Yes 56.4 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 525.0 1,075.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker (5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k Ibs and S/O 112k lbs. Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water /sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Dowell kick out top plug w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls /stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k Ibs to 85k lbs. Landed on hanger at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. Cement Fluids &Additives '''' Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Biozan Pre Flush 35.0 Yield (W /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Additives Additive Type Concentration Conc Unit label Biozan Additive Type Concentration Conc Unit label Fresh Water Additive Type Concentration Conc Unit label Nut Plug IFitiid - Fluid Type Fluid Description Estimated Top (ftKB) G Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 54.2 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Page 1/2 Report Printed: 2/20/2012 oU , ,111 ll l'1 1 1 Cement Detail Report I I�I� k al11 n la + I 0 ,1 CD3 -199 h l u l l g l � lq ui i l i^N 1 ,1111 "'u V 1 Ww iu1, ui I lii i , I o p ,DoVIII i 1 1j V l Conoc Phill II String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/7/2011 00:00 Additives Additive Type Concentration Conc Unit label Mudpush II Cement Fluids & Additives - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) AS Lite Lead 26.5 2,016.4 308 247.3 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.51 20.70 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) G- Tail 2,016.4 2,673.0 272 G 56.3 Yield (ft/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.11 15.80 54.9 4.50 Additives Additive Type Concentration Conc Unit label S -002 accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D - 046 antifoamer 0.2 %BWOC Additive Type Concentration Conc Unit label D - 065 dispersant 0.3 %BWOC Page 2/2 Report Printed: 2/20 /2012 1,11111�1 x Security Level: AK Development Daily Drilling Report i���i ��lil1 �+ 1 � �lllU ih , mrr "� ui _;n „liu q l 1I,I Il�l CD3 -199 R d i ' l ' I' i Report Number: 4 iCo coPhiflips f Rig: DOYON 141 Report Date: 2/10/2011 AFE Type Network/ID #_' Total' AFE +Sub ---„ ' 10296871 7,774,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 199 Development FIORD NECHELIK 3.08 4.0 0.00 2,673.0 2,673.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 13,486.18 49,262.80 432,363.24 1,011,227.04 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 23.19 2.51 3/2/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,662.8ftKB Ops and Depth @ Morning Report 24hr Forecast Installing well head Install wellhead and N/U 13 -5/8" BOPE. Test same. P/U 8 -3/4" intermediate drilling BHA. Last 24hr Summary Finish conditioning and circulating mud from 9.6 ppg to 10.0 ppg. POOH on elevators to HWDP at 906' MD (19 stands DP). L/D 6 joints of 5" HWDP and rack back remainder of HWDP (6 stands). .Reciprocated through several tight spots between 800' - 600' MD. L/D MWD tools and bit. Rig up casing running equipment. M/U 9 -5/8" 40# L -80 BTC -M shoe track and circulate 60 bbls through Frank's fill -up tool. Continue running casing to shoe setting depth of 2662.88' MD. Broke circulation on joints #29 - 30 and #62 - 64 while RIH. Circulated 194 bbls (surface to surface) on joint #35 at 1410' MD. Land hanger and R/U cementing equipment. Establish circulation down 9 -5/8" casing and stage up rate to 7 bpm. Condition and circulate mud to reduce PV/YP in preparation for cementing. PJSM on cementing. Pump 90 bbls of 10.0 ppg mud with nut plug marker followed by 35 bbls of 8.34 ppg Biozan preflush with nut plug marker. Switch over to Dowell and pump 5 bbls water. Pressure test lines to 3500 psi. Drop bottom plug and pump 54.2 bbls Mud Push II spacer. Pump 247.3 bbls AS lite lead cement followed by 56.3 bbls Alpine tail cement. Drop top plug and kick out with 20 bbls water using Dowell unit. Displace cement with rig mud pump #1 and 10.0 ppg mud. Bump plug at 1750 strokes (175.8 bbls) and pressure up to 1075 psi. Hold pressure for 5 minutes. CIP at 23:59 hrs on 2/10/2011. Landed hanger on landing ring. Circulated 56.4 bbls of good 10.7 ppg cement to surface. General Remarks Weather Head Count No Incidents, No Accidents. Rig & camp on Hi -line. -20° Wind SW @ 10 MPH, Patchy fog and 41.0 flurries Supervisor _- Title Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Elmo Cecchetti, Rig Supervisor Rig Supervisor , 1 1:111:1111111 1 11110110 - 1=;= - - Time Log - Start " End Dur - Time _- ', Depth Start Depth' -End _ • . Time Tim " (hrs) Phase _ , Op Code Activity Code 0 ` = Trbl Cade .' ; ' Trb1 Class. (ftKB) (ttKB), Operation 00:00 00:30 0.50 SURFAC DRILL TRIP P 2,300.0 2,673.0 RIH 4 stands of drill pipe racked back during conditioning and circulating of mud. No fill encountered. 00:30 01:00 0.50 SURFAC DRILL OWFF P 2,673.0 2,673.0 Monitor well on trip tank for flow. 01:00 02:30 1.50 SURFAC DRILL TRIP P 2,673.0 906.0 POOH on elevators from 2673' MD to HWDP at 906' MD (19 stands DP). No hole problems encountered. 02:30 03:30 1.00 SURFAC DRILL PULD P 906.0 170.0 Check well for flow (10 minutes) then L/D 6 joints of 5" HWDP. Rack back remainder of HWDP (6 stands). Recorded overpull at 790', 730', 640', and 610' MD. Reciprocated through each spot several times until no drag was observed. 03:30 04:45 1.25 SURFAC DRILL PULD P 170.0 0.0 L/D jars and NMFDC. Break bit and drain motor. Small piece of wood found lodged in bit. Bit grade: 1- 2- WT- 2- E- 2 -NO -TD 04:45 06:00 1.25 SURFAC DRILL PULD P 0.0 0.0 Download MWD. Break out and L/D MWD tools. 06:00 06:30 0.50 SURFAC DRILL PULD P 0.0 0.0 Lay down tools from the rig floor. 06:30 07:00 0.50 SURFAC DRILL OTHR P 0.0 0.0 Clean rig floor. Latest BOP Test Data Date Comment Page 1/5 Report Printed: 2/20/2012 jj Security Level: AK Development r Daily Drilling Report CD3 -199 Cc�tncaCt6'hiirias Report Number: 4 Rig: DOYON 141 Report Date: 2/10/2011 Time Log Start End . Our Titne Depth Start, Depth End Time Time (hrs) Phase Op Code Activity Code F - T - Trbt Code Trbl Class. (ftK8), (ftK8) Operation 07:00 07:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Pre job safety meeting on rigging up to run casing. 07:15 08:30 1.25 SURFAC CASING RURD P 0.0 0.0 Rig up casing running tools for 9 -5/8" casing (long bales, elevators, slips, tongs). 08:30 08:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Pre job safety meeting on running 9 -5/8" 40 ppf L -80 BTC -m casing. 08:45 09:45 1.00 SURFAC CASING RNCS P 0.0 105.0 M/U 9 -5/8" casing shoe track as per detail: Rays Oil tool float shoe joint, thread lock joint, HES Sure Seal II float collar joint. All baker locked. 09:45 10:00 0.25 SURFAC CASING CIRC P 105.0 115.0 Circulate 60 bbls through float equipment using Franks fill -up tool with 9 -5/8" shoe above conductor shoe at 108'. Circulate 3 bpm, 4 bpm, 5 bpm, and 6 bpm. 10:00 12:00 2.00 SURFAC CASING RNCS P 115.0 1,085.0 Continue running casing to noon depth of 1085' MD (27 joints). Baker lock pin of 4th joint. Make up torque 10,000 ft lbs. Installed centralizers as plan: 10' above shoe on stop ring, collar of joint #1, 10' below box of joint #2 on stop ring. Every collar to joint # 13, then every odd joint to joint # 63. Use Run -N -Seal dope on threads. 12:00 12:30 0.50 SURFAC CASING RNCS P 1,085.0 1,205.0 Circulate joint #29 and #30 in hole with Frank's fill -up tool due to THICK MUD and short displacement volume. Pump 20 bbls each at 2 bpm while running each joint. 12:30 13:00 0.50 SURFAC CASING RNCS P 1,205.0 1,370.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1205' T/ 1370' (joint 34 in the hole). 13:00 13:45 0.75 SURFAC CASING CIRC P 1,370.0 1,410.0 Make up joint # 35, stab Frank's fill -up tool. Circulate 194 bbls (surface- surface), reciprocate 20' F/ 1410' T/ 1390', staging up F/ 2 bpm T/ 3.5 bpm. After 70 bbls pumped, increase pump rate to 4 bpm, after 90 bbls increase to 5 bpm, after 120 bbls increase pump rate to 6 bpm w/ 400 psi. 13:45 15:30 1.75 SURFAC CASING RNCS P 1,410.0 2,475.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1410' T/ 2475' (jt # 61 in the hole). 15:30 16:15 0.75 SURFAC CASING RNCS P 2,475.0 2,590.0 While running joint # 62, # 63 and #64, stab frank's tool and pump 4 bpm while running each joint f/ 2475' to 2590'. Pumped 97 bbls total. Circulated joints in the hole due to THICK MUD and short displacment volume. 16:15 16:30 0.25 SURFAC CASING RNCS P 2,590.0 2,630.0 Run joint #65 F/ 2590' T/ 2630'. 16:30 16:45 0.25 SURFAC CASING RURD P 2,630.0 2,630.0 Rig down Frank's fill -up tool. Blow down the top drive. Page 2/5 Report Printed: 2/20/2012 aii °l'�l'uh "Ilu Security Level: AK Development Daily Drilling Report �g CD3 -199 CvtaccsPhilfi Report Number: 4 Rig: DOYON 141 Report Date: 2/10/2011 ` Ti m e Log Start End, Dur =- Time . Depth Start Depth End Time Time (I1rsT_- Phase Op Code Activity, Code =_ - P -T -X Trbl Code Trtil Class EftKBX ' (ftKSI Operation 16:45 17:00 0.25 SURFAC CASING RNCS P 2,630.0 2,662.9 Make up FMC hanger and landing joint. Remove casing slips. RIH f/ 2630' to land shoe at 2662.88'. PU wt 132k, SO wt 97k. 17:00 17:30 0.50 SURFAC CEMENT RURD P 2,662.9 2,662.9 Rig up Dowell /Schlumberger cement head and lines. 17:30 21:00 3.50 SURFAC CEMENT CIRC P 2,662.9 2,662.9 Establish circulation at 3 bpm with 300 psi. Stage pumps up to 7 bpm with 400 psi. Pumped a total of 1015 bbls. Circulate and condition mud to reduce PV/YP from 40/67 to 34/29. Reduce funnel viscosity from 300 sec /qt to 80 sec/qt. Reciprocate F/ 2662' to 2642' during circulation. 21:00 21:15 0.25 SURFAC CEMENT SFTY P 2,662.9 2,662.9 PJSM for cementing 9 -5/8" casing with rig crew, cementers, mud engineers, and truck drivers. 21:15 22:00 0.75 SURFAC CEMENT CIRC P 2,662.9 2,662.9 Pump 90 bbls of 10.0 ppg mud with nut plug marker (5 ppb) at 6 bpm with 330 psi. Next pumped 35 bbls of 8.34 ppg Biozan preflush with nut plug marker (5 ppb) at 5 bpm with 200 psi. Reciprocated 15' to 20'. P/U 122k lbs and S/O 112k lbs. 22:00 23:15 1.25 SURFAC CEMENT PUCM P 2,662.9 2,662.9 Dowell pump 5 bbls water and pressure test lines to 3500 psi, good. Bleed off pressure and drop bottom plug. Mix and pump 54.2 bbls Mud Push II spacer (10.5 ppg), pump at 6 bpm w/ 230 psi. Mix and pump 247.3 bbls (308 sx) AS lite lead cement (10.7 ppg, 4.51 cuft/sx, 20.7 gal water /sx), pump at 6.3 bpm with 150 psi. Mix and pump 56.3 bbls (272 sx) Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.105 gal water /sx), pump at 5.8 bpm with 200 psi. Shut down and drop top plug. Page 3/5 Report Printed: 2/20/2012 Security Level: AK Development Daily Drilling Report „ '„ l�i CD3 -199 CanocoPhilli�s uuWl'i „ Report Number: 4 Rig: DOYON 141 Report Date: 2/10/2011 Time Log Start End ' Our Time Depth Start pepth Time ` Time (hrs)- Phase Op Code - Activity Code P -T -X_ - _ Trbl Code Trb6'Glass. (fE)`' ' (tt ) Operation - 23:15 00:00 0.75 SURFAC CEMENT DISP P 2,662.6 2,662.9 Dowell kick out top p 9 lu w/ 20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump #1 and 10.0 ppg mud. Pump at 7 bpm with initial circulating pressure of 300 psi. After 9p P pumping 160 bbls at 7 bpm and a final circulating pressure of 700 psi, slowed rate to 3 bpm. ICP at 3 bpm was 500 psi with a FCP of 525 psi. Bump plug at 1750 strokes, 175.8 bbls (calculated displacement of 1755 strokes with 0.1005 bbls /stroke) and pressured up to 1075 psi. Held pressure for 5 minutes. CIP @ 23:59 hrs 2/10/2011. Note: Reciprocated until S/O decreased from 112k lbs to 85k lbs. Landed hanger on landing ring at 2345 hrs (landed at 800 strokes into displacement which was 40 bbls before cement returns). Circulated 56.4 bbls of good 10.7 ppg cement to surface. Mud Check Data YP Calc Gel (los) Gel (10m)I' Get (30m) ttTHP Flit Density Temp Solids, Corr., Type r' Depth (ftKB) Dens (lb/gal) Vis (s /qt)' PV,Oalc (cp) (IV/VOW) (IbfM00ft=) (Ibf/100ft MBT (Ibibbt) _ `(mt /30miri) pH ( ° F)= _ (% Spud Mud 2,673.0 10.00 43.0 83.0 98.000 32.0 8.6 68.0 Spud Mud 2,673.0 10.00 8.0 32.0 38.000 32.0 8.7 64.0 „Injection Fluid .. Fluid ' Source From Lease (bbl) Destination Vendor Manifest Number Note Drilling Mud WBM CD3 -199 200.0 CD1 -19 AES 307329 Drilling Mud WBM CD3 -199 90.0 CD1 -19 AES 307330 Welibores = Wellbore Name Wellbore API /UWI CO3 -199 501032063500 Section ” Size (in)_, Act, Top (MO) Act "Btm (ftKB) Start Dace } End Gate SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Page 4/5 Report Printed: 2/20/2012 • I� P Ilil Security Level: AK Development n b Daily Drilling Report jp, ,I �i o CD3 -199 cotnc�spttliips ' Report Number: 4 Rig: DOYON 141 Report Date: 2/10/2011 Casing Strings ft String CO StringWt Casing Desorption Run Date (in) (lbstft) String Grade; ' Set Depth (ftKS) Comment - SURFACE 2/10/2011 9 5/8 40.00 L -80 2,662.8 PJSM on running 9 -5/8" 40 ppf L -80 BTC -m casing. M/U 9 -5/8" casing shoe track as per detail: Rays Oil tool float shoe joint, thread lock joint, HES Sure Seal II float collar joint. All baker locked. Circulate 60 bbls through float equipment using Franks fill -up tool with 9 -5/8" shoe above conductor shoe at 108'. Circulate 3 bpm, 4 bpm, 5 bpm, and 6 bpm. Continue running casing to noon depth of 1085' MD (27 joints). Baker lock pin of 4th joint. Make up torque 10,000 ft lbs. Installed centralizers as plan: 10' above shoe on stop ring, collar of joint #1, 10' below box of joint #2 on stop ring. Every collar to joint # 13, then every odd joint to joint # 63. Use Run -N -Seal dope on threads. Circulate joint #29 and #30 in hole with Frank's fill -up tool due to THICK MUD and short displacement volume. Pump 20 bbls each at 2 bpm while running each joint. Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1205' T/ 1370' (joint 34 in the hole). Make up joint # 35, stab Frank's fill -up tool. Circulate 194 bbls (surface- surface), reciprocate 20' F/ 1410' T/ 1390', staging up F/ 2 bpm T/ 3.5 bpm. After 70 bbls pumped, increase pump rate to 4 bpm, after 90 bbls increase to 5 bpm, after 120 bbls increase pump rate to 6 bpm w/ 400 psi. Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing F/ 1410' T/ 2475' (jt # 61 in the hole). While running joint # 62, # 63 and #64, stab frank's tool and pump 4 bpm while running each joint f/ 2475' to 2590'. Pumped 97 bbls total. Circulated joints in the hole due to THICK MUD and short displacment volume. Run joint #65 F/ 2590' T/ 2630'. Rig down Frank's fill -up tool. Blow down the top drive. Make up FMC hanger and landing joint. Remove casing slips. RIH f/ 2630' to land shoe at 2662.88'. PU wt 132k, SO wt 97k. Cement Surface Casing Cement - Started A 2/10 /2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 199 SURFACE, 2,662.8ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 26.5 2,673.0 3 525.0 Fluid, class Amount (sacks) 3t (bbl) >_ " Density (ib /gal)'; Yield;(ft' /sack) Est Top MKS) Est Btm (ftKB) Biozan Pre Flush 35.0 10.00 Mud Push 54.2 10.50 AS Lite- Lead 308 247.3 10.70 4.51 26.5 2,016.4 G- Tail G 272 56.3 15.80 1.16 2,016.4 2,673.0 Page 5/5 Report Printed: 2/20/2012 ' 0, , Security Level: AK Development Daily Drilling Report ft 0:44: i r y ew CD3 -199 c,QCrttiltp III1 Report Number: 5 Rig: DOYON 141 Report Date: 2/11/2011 AFE Type NetworkllD # Total "AFE -*Sup ° ' 10296871 7,774,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) • CD3 - 199 Development FIORD NECHELIK 4.08 5.0 0.00 2,673.0 2,673.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 26,213.14 75,475.94 349,024.44 1,360,251.48 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 24.19 1.51 3/3/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,662.8ftKB Ops and Depth c Morning Report 24hr Forecast P/U and rackback 5" DP Finish P/U and rackback 54 stands 5" DP. M/U BHA #3 and RIH. Test casing to 3500 psi. Drill cement and 20' of new formation. Perform LOT to 18 ppg EMW. Drill 8 -3/4" intermediate hole section. Last 24hr Summary Bled off pressure to check floats on the 9 -5/8" 40 ppf L -80 BTC -m casing, OK. R/D and L/D FMC landing joint, casing, and cementing equipment. N/D riser and FMC starter head. N/U FMC wellhead and test metal -metal seals, OK. N/U 13 -5/8" BOPE. Modify drilling riser to fit rig elevation and N/U same. Test BOPE to 250 psi low / 3500 psi high except for annular to 2500 psi high. Bob Noble, AOGCC Inspector witnessed testing. RID BOPE testing equipment and R/U DP handling equipment. P/U and rackback 18 joints of 5" DP. Break operations for all hands to attend Theoretical Maximum Performance (TMP) discussion facilitated by RLG. General Remarks Weather Head Count No Incidents, No Accidents. Rig & camp on Hi -line. -29° F / Windchill -54 °F, SSW @ 12 MPH 41.0 - Supervisor __ -` = Title ' " Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Elmo Cecchetti, Rig Supervisor Rig Supervisor .Time Log Start i End Dur -_ , , - -- _ „. Time Depth Start Depth End Time Time (firs), __ Phase Op -Code Activity Code P-T-X Trbl Code Trbl- Class. (ftKB) (ftKB }', Operation 00:00 00:15 0.25 SURFAC CEMENT OTHR P 2,662.9 2,662.9 Bled off pressue to check floats on the 9 -5/8" 40 ppf L -80 BTC -m casing. Floats holding. 00:15 00:30 0.25 SURFAC CEMENT SFTY P 2,662.9 2,662.9 PJSM on R/D cementing equipment and landing joint. 00:30 02:00 1.50 SURFAC CEMENT RURD P 2,662.9 0.0 R/D Dowell cement head, back out/lay down FMC landing joint. R/D casing tools. Flush riser and lines of cement. 02:00 05:00 3.00 SURFAC WHDBOP NUND P 0.0 0.0 N/D riser and FMC adapter /starter head. Prepare hanger for wellhead installation. 05:00 07:45 2.75 SURFAC WHDBOP NUND P 0.0 0.0 Bring FMC wellhead equipment into cellar. N/U same. 07:45 08:00 0.25 SURFAC WHDBOP PRTS P 0.0 0.0 Test metal -metal seals to 1000 f/ 10 minutes. Witness of test by rig supervisor. 08:00 09:30 1.50 SURFAC WHDBOP NUND P 0.0 0.0 N/U 13 -5/8" BOPE. 09:30 10:00 0.50 SURFAC RIGMNT SVRG P 0.0 0.0 Service rig. 10:00 12:00 2.00 SURFAC WHDBOP OTHR P 0.0 0.0 Modify drilling riser to fit rig elevation. Add some length. Clean pits. Double valve annulus valve. 12:00 13:00 1.00 SURFAC WHDBOP RURD P 0.0 0.0 N/U riser and flow line. Rig up to test BOPE. 13:00 13:30 0.50 SURFAC WHDBOP OTHR P 0.0 0.0 Fill hole. Flood choke manifold and BOP stack. Check for leaks, OK. 13:30 13:45 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 PJSM on testing BOPE. Latest BOP Test Data . Da1Ce '>. .;]; Comment " ' 2/11/2011 Witness of test by AOGCC inspector Bob Noble. Page 1/3 Report Printed: 2/20/2012 Security Level: AK Development ll 11111 , " , ' Daily Drilling Report t1 �,, 1 Plw CD3 -199 i9 � Report Number: 5 ConocoPhillips jj1j °iilliVa Rig: DOYON 141 Report Date: 2/11/2011 Time Log Start End Time Depth Start DepthEnd lime Time,'' (hrs) ; -- Phase Op Code A ctivity Code_ P - - Trb4 Code Trbl Class. {ftKB) (ftKPlillr Operation 13:45 20:15 6.50 SURFAC WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test by AOGCC inspector Bob Noble. All tests charted for 5 minutes each. Tested annular to 250 psi and 2500 psi. Tested all valves in choke manifold, choke line, kill line, 4" demco valve on mud line, floor safety valve, IBOP, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (2 -7/8" x 5" variable bore) to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Performed accumulator test: initial system pressure was 3000 psi, pressure after closure was 1700 psi. Build up 200 psi in 40 seconds and full pressure in 3 minutes 34 seconds. Nitrogen bottles average 2000 psi. Tested PVT and gas alarms. Choke manifold valves #8,9, and 10 required replacing stem packing. Lower VBR's required retesting. 20:15 20:30 0.25 SURFAC WHDBOP RURD P 0.0 0.0 R/D BOPE test equipment. Install wear ring. Blow down kill line, choke line, and choke manifold. 20:30 20:45 0.25 SURFAC DRILL RURD P 0.0 0.0 R/U to P/U DP via mouse hole. 20:45 21:00 0.25 SURFAC DRILL SFTY P 0.0 0.0 PJSM on P/U DP. 21:00 21:30 0.50 SURFAC DRILL PULD P 0.0 0.0 P/U and M/U 18 joints of 5" DP. Rack back same. 21:30 00:00 2.50 SURFAC DRILL OTHR P 0.0 0.0 Break for all hands to attend Theoretical Maximum Performance (TMP) facilitated by RLG. Note: Excellent participation from both crews. Discussed potential methods to increase efficiency without compromising safety during flat time operations. Developed over 50 action items to investigate for optimizing operations. Feedback provided by crews showed enthusiasm and support for the TMP purpose. Mud Check=°-Data ...... vP ca o e�= taus} faef (loin) del (30ml ; : ttT Tilt Density Temp : Solids Corr Type D Dens(tb/gal) Vis (s/qt) PVCalc(cp)_ _ (Ibf/100tt') (Ibf /100ft (Ibf1)00ft (bt/tQ : ':CmtJ3tlmin)- p�{' ("F) {9f) Spud Mud 2,663.0 10.00 8.0 32.0 38.000 32.0 8.7 64.0 Spud Mud 2,663.0 10.00 8.0 32.0 38.000 32.0 8.7 66.0 Injection Flutd Flu d Source Trom Lease:(bbl Destination Vendor Manifest Nuf i )er , : Nate Cuttings CD3 -199 96.4 G & I AES 307338 20 CU YD Cuttings CD3 -199 96.4 G & I AES 307339 20 CU YD Drilling Mud WBM CD3 -199 290.0 CD1 -19 AES 307336 Drilling Mud WBM CD3 -199 280.0 CD1 -19 AES 307333 Page 2/3 Report Printed: 2/20/2012 u „ o ,, Security Level: AK Development ' "'` i a „ ! I "' Daily Drilling Report 1� 4 ii�e- ,41„„:1111,400.i ';;ld�l4 CD3 -199 id* Report Number: 5 ConocoPhiiiips .10f Rig: DOYON 141 Report Date: 2/11/2011 Injection Fluid r Fluid Source From Lease (bbi) Destination' Vendor Manifest Number Note Drilling Mud WBM CD3 -199 280.0 CD1 -19 AES 307337 Drilling Mud WBM CD3 -199 275.0 CD1 -19 AES 307331 Drilling Mud WBM CD3 -199 270.0 CD1 -19 AES 307341 Drilling Mud WBM CD3 -199 200.0 CD1 -19 AES 307334 Drilling Mud WBM CD3 -199 180.0 CD1 -19 AES 307343 Drilling Mud WBM CD3 -199 130.0 CD1 -19 AES 307340 Drilling Mud WBM CD3 -199 90.0 CD1 -19 AES 307342 Welibores Wellbore Name Wellbore API /UWI CD3 -199 501032063500 Section Size (in) Act Top.(ftKB) Act Btm (ftKB) ' Start Date ` End Date -_ SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Pressure Test Data - Item Tasted Date Pres (psi) Detection = Comment BOP stack, 2/11/2011 13:45, 2/11/2011 3,500.0 No Witness of test by AOGCC III inspector Bob Noble. p Page 3/3 Report Printed: 2/20/2012 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-199 Rig: Doyon Rig 141 Date: 2/12/2011 Volume In • ut Volume/Stroke Pum • Rate: Drilling Supervisor: Rizek 1 Cecchetti Pump used: #2 Mud Pump v Strokes W 0.1005 Bbls/Strk 5.00 Strk/min ■ Type of Test: Casing Shoe Test LOT/FIT ■ Pumping down annulus and DP. ■ - Casing Test Pressure Integrity Test Hole Size: 8-3/4" v Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 25 .OJFt 2662.91Ft-MD1 2457.OIFt _ 2 I 2480.21Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ■ 0 0 0 3730 0 0 0.00 1015 Casing Test Pressure IntearitvTest 1 40 1 3730 2 125 0.25 925 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 2 90 2 3730 4 375 0.50 875 Mud 10 min Gel: 20.0 Lb/100 Ft2 Mud 10 min Gel: 12.0 Lb/100 Ft2 3 200 3 3730 6 525 1.00 775 Test Pressure: 3500.0 psi Rotating Weight: 96000.0 Lbs 4 325 4 3730 8 675 1.50 750 Rotating Weight: 9200.0 Lbs Blocks/Top Drive Weight: 35000.0 Lbs 5 475 5 3730 10 800 2.00 725 Blocks/Top Drive Weight: 35000.0 Lbs Desired PIT EMW: 18.0 ppg 6 625 6 3730 12 925 2.50 700 Estimates for Test: 2.8 bbls Estimates for Test: 1073 psi 0.7 bbls 7 775 7 3730 14 975 3.00 690 v v 8 875 8 3730 16 1005 3.50 675 EMW = Leak-off Pressure + Mud Weight = 925 + 9 6 PIT 15 Second 9 970 9 3730 18 1015 4.00 675 . 0.052 x TVD 0.052 x 2457 Shut-in Pressure, psi 10 1050 10 3730 4.50 675 .„ .,-. EMW at 2662.88 Ft-MD (2467.01 Ft-TVD) = 168 ppg 925 11 1140 15 3730 ;;;;;;;;;:::i::i;i:::i:i:i:i: 5.00 675 4000 Lost 10 psi during test, held 12 1240 20 3725 1:;: 5.50 675 k 99.7% of test pressure. ,7 4 13 1340 25 3720 6.00 675 „ 3500 14 1450 30 3720 „ ' "0":::'::'':: 6.50 665 15 1540 ;;;:;;;; 7.00 665 3000 16 1650 :'n:;';:;:::: i:;:;:;:;;;:;:;;; 7.50 665 18 1870 ::'::"':':':::':::::: 8.00 665 LIJ 2500 20 2140 :;:: :::::' :::: 8.50 665 cc , 22 2400 ;;;;;;;;;;;;;;;: ;;;;:;:;:::1::: 9.00 665 m - . 24 2640 :::i::;:::::::'::;:::;:::!: 9.50 665 (I) 2000 0) W ' 26 2930 H;;;;;:::; . ,;, ::::: 10.00 665 rt a. 1500 28 3170 , . 30 3430 32 3730 1000 _. „, „: , L ",,,m• .,,,,,, ""l''' '''] ., , ,.• ., • ' ^ ,„ - 500 , , ... 0 0 1 2 3 4 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume illfm•CASING TEST -a-LEAK-OFF TEST 0 PIT Point 3PumpeBbls d Bled Bac _ 1.8 k Pumped Bled Back .2 3bIs Bbls 0.8IBbls Comments: , ■ Cu- i Jul fete lAtbillg Test an kir z- 1L-Lu i i .xis Summary CD3 -199 Intermediate Well: CO3 - 199 fP $ _ 322320 � �. ` ° =�' �-_: �"tu' ==`� Casino Date: ,s�;a�; , ConocoPhillips I Rig: ooyon 14 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 FIn " RKB to Casing Flange (Load shoulder ,62 below LLDS) , (LLDS 24.8$ ) 24.88 FMC 7" Mandrel hanger to the lower lock down screws 1.00 24.88 7 ", 26 #, L -80, BTC -m Casing Pup jt Pin x Pin 2.24 25.88 Jts 87 to 214 128 Jts 7 ", 26 #, L - 80, BTC - Casing 5296.46 28.12 HES 7 " St C 2.43 5324.58 Jts 4 to 86 83 Jts 7 ", 26 #, L - 80, BTC - Casing 3415.67 5327.01 HES Shut - off Baffle Collar 1.00 8742.68 Jts 3 to 3 1 Jts 7 ", 26 #, L - 80, BTC - Casing 40.90 8743.68 HES Sure Seal ll Float Collar w/ By - Pass Baffle Adapter 1.01 8784.58 Jts 1 to 2 2 Jts 7 ", 26 #, L - 80, BTC - Casing 81.99 8785.59 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 8867.58 Bottom of shoe >» 8869.70 8 -3/4" Hole TD © 8879' MD / 6953/ ' TVD, Hole angle 82.57 8869.70 7" Shoe © 8869.7' MD / 6952.72' TVD/ Hole angle 82.57 deg 8869.70 8869.70 Quannik @ 4786' MD (4061' TVD) 8869.70 8869.70 8869.70 Total of 89 Straight Blade centralizers (7" x 8 -3/8 ") - 5 Stop Collars 8869.70 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 8869.70 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 8869.70 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 8869.70 1 Straight Blade centralizer per jt on jts # 4 - #30 floating 8869.70 8869.70 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. # 86- below stage collar 8869.70 1 Staight Blade centralizer w/ stop 10' above Stage Collar -Jt. # 87 8869.70 1 Straight Blade centralizer per joint floating # 88 thru # 111 8869.70 8869.70 1 on 3 jts Across Shoe jts # 151, # 152 & # 153 8869.70 then 1 every other jt # 155 to # 213 - -- 2 joints below WH 8869.70 8869.70 Planned: 237 jts in pipe shed / 214 jts to run. 240 jts on location. 8869.70 23 joints left in the shed, plus 3 outside= 26 jts left over 8869.70 8869.70 8869.70 Remarks: Drifted w/ 6.151" plastic rabbit Up Wt ? ?? K Average MU torque= 7800 Ft Ibs Dn Wt ?? K Used Run -N -Seal dope Block Wt 35 K Supervisors: Fred Herbert / Granville Rizek / Mark Brouillet IP } , l r r � 4 , I, I°V il'u, Cement Detail Report '` CD3 -199 i l l y , IIV�a4 : �. � II II t1:11, . hE .. Con ocopin V 4111III String: 7" Intermediate casing Job: DRILLING ORIGINAL, 2/7/2011 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7" Intermediate casing 2/23/2011 17:00 2/23/2011 21:15 CD3 - 199 Comment Pump surface volume CW100 pressure test cement line to 3,500 psi, Continue pumping CW100, Drop top plug 25 bbl's CW100 pumped, Pump 5 bbl's CW100 total CW100 pumped 30 bbl's. batch and pump 27 bbl's 11.5 ppg Mudpush II spacer, Batch cement and pump 15.8 ppg lead slurry, volume pumped 53 bbl's. Shut down drop top plug chase with 20 bbl's water, Turn over to rig displace at 5 bpm bump plug at 3,104 strokes total mud pumped 314 bbl's. . Casing reciprocated 20' stroke length throughout job up wt 245k do wt 145k, Casing landed on hanger with CIP @ 18:57. final circulating pressure 400 psi, Pressure up 700 psi over FCP held for 5 minutes, bled pressure off checked floats ( Floats Good) Pressure up to 3,400 psi to open stage collar at 5,324' md. Circulate and condition mud for 2nd stage cement job. @ 5 bpm - 300 psi, Increased rate to 6 bpm - 600 psi 2nd stage cement job, Pump 30 bbl's pumped, Pump 28 bbl's 11.5 ppg Mudpush II spacer, Mix and pump 48 bbl's 15.5 ppg tail slurry, Drop top plug, Flush cement lines with water turn over to rig displace cement with 184 bbl's mud, Displace at 6 bpm - 270 psi, Bump plug with 1,790 strokes, Pressure up to 1,850 psi close stage collar, (Stage collar @ 5,324' md) pressure up to 2,300 psi hold for 5 minutes, bleed pressure confirm stage collar closed. CIP @ 21:09 :C Sta - ;Stage # 1 . Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? 7" Intermediate casing 1st stage cement job 7,810.0 8,879.0 No 0.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 5 4 400.0 1,100.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Flu & Additive = - 'Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 8,867.0 7,810.0 215 G 53.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label Retarder B155 0.08 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC `Stage # 2 : : 0 :. ... _, ' . � ° Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 7" Intermediate casing 2nd stage cement job 4,285.0 5,325.0 No 0.0 Yes No Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 6 5 270.0 1,850.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dement &-Additives := fit, :�. P ,r0 41; !)Ft i i!" ,0:' -,_ r . fi t. :'` Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,285.0 5,324.0 186 G 48.0 Yield (ft' /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.01 15.80 5.03 Additives Additive Type Concentration Conc Unit label Retarder B155 0.08 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 2/20/2012 Security Level: AK Development Daily Drilling Report de l CD3 -199 CotatOPhillips Report Number: 16 Rig: DOYON 141 Report Date: 2/22/2011 AFE Type _ NetworktlD # Tota1 AFE +Sup 10296871 7,774,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 199 Development FIORD NECHELIK 15.08 16.0 0.00 8,879.0 8,879.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,495.20 478, 328.18 131, 689.20 3, 369, 297.16 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 27.18 - 1.48 3/6/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 8,870.0ftKB Ops and Depth @ Morning Report 24hr Forecast Running casing @ 5600' Run casing & Cement Last 24hr Summary Short trip, Circulate bottoms up, Spot Well bore strengthening pill @ 8,879' Follow with 10.4 ppg mud to bit, Monitor well, Pull out spotting WBSP & Cpr @ 2 bpm F/8,879' MD - T/7,790' MD. Trip out of hole on elevators, Monitor at BHA, Rack back HWDP and Jars, Lay down BHA, Flush stack pull and service WB, Clear and clean floor, Cut 78' drill line, Change upper rams to 7" (Sim ops while cutting drill line) Test rams,250 low - 3,500 high. Rig down test equip, Set 10 -3/8" Wear ring. PJSM rig up and run 7" casing T/ 2,640' MD. Circulate casing volume staging pumps up to 5 bpm w/ 375 psi. General Remarks Weather Head Count No Incidents, No Accidents. Rig & camp on Hi -line. -18° Winds South East @ 9 MPH, Wind Chill 46.0 -28° Supervisor ' Title Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Mark Brouillet, Rig Supervisor Rig Supervisor Time tog Start a End Dur Time Depth Start; <- Depth End -_'- Time -Time (hrs) Phase Op Code Activity Code P T " Trbl Code Trbi Class. (ftKB) ''' (ftKS) Operation 00:00 00:30 0.50 INTRM1 DRILL WPRT P 8,810.0 8,347.0 Short trip f/ 8810' to 8347'. PU wt 205k, So wt 145k. 20k overpull @ 8795' and 10k overpull @ 8760'. 00:30 01:00 0.50 INTRM1 DRILL WPRT P 8,347.0 8,879.0 Monitor well- static. RIH, tag bottom @ 8879', no problems. 10k drag @ 8830' and 8845'. Wipe f/ 8755' to 8770' 01:00 02:00 1.00 INTRM1 DRILL CIRC P 8,879.0 8,879.0 Break circulation @ 8879' w/ 400 gpm, rotate 120 rpm w/ 10k ft lbs of torque. Stage pumps up to 600 gpm w/ 1500 psi. Circulate bottoms up while recip f/ 8879' to 8810'. 02:00 02:30 0.50 INTRM1 DRILL CIRC P 8,879.0 8,810.0 Pump 10 bbl wellbore strength pill, follow w/ 90 bbl casing running pill, chase w/ 68 bbl 10.4 ppg mud. Pull up f/ 8879' to 8810' at 25' /min pulling speed, pumping 20 spm w/ 200 psi. Wellbore strength pill: Sak Black 5 ppb, Safe Carb 20 5 ppb. Casing running pill: Alpine Beads 5ppg, Lube 776 6 %. 02:30 02:45 0.25 INTRM1 DRILL OWFF P 8,810.0 8,810.0 Monitor well- static. Blow down the top drive. 02:45 03:15 0.50 INTRM1 DRILL TRIP P 8,810.0 8,530.0 Pump and Pull f/ 8810' to 8530'. Pump 20 spm f/ 75 strokes per stand. Pull 25'/minute. Record PU and SO wt's. Overpull @ 8792' (10k over) 03:15 03:45 0.50 INTRM1 DRILL OWFF P 8,530.0 8,530.0 Monitor well- static. RIH one stand. Determine not lined up right on pits. Sucking f/ pill pit (wellbore strength fluid), returns to pit #5- gaining fluid. Line up to suck and return f/ pit #5. Latest BOP Test Data Date Comment -_ - " 2/11/2011 Witness of test by AOGCC inspector Bob Noble. Page 1/2 Report Printed: 2/20/2012 Security Level: AK Development 1 1 r Daily Drilling Report CD3 -199 cc�lr�iliip Report Number: 16 Rig: DOYON 141 Report Date: 2/22/2011 Time Log Start End Dur . Time', Depth Start Depth End" Time Time (Ors) Phase Op Code Activity Cade P -T.X TrbtCode, Trill Class. MKS) ,, (ftKB), '- Operation 03:45 05:00 1.25 INTRM1 DRILL TRIP P 8,530.0 7,787.0 Pump and Pull f/ 8530' to 7787' (77 stands in the hole). Pump 20 spm f/ 75 strokes per stand. Pull 25' /minute. Record PU and SO wt's. 05:00 05:15 0.25 INTRM1 DRILL OWFF P 7,787.0 7,787.0 Monitor well- static. 05:15 06:15 1.00 INTRM1 DRILL TRIP P 7,787.0 6,862.0 Pull out on the trip tank f/ 7787' to 6862' 06:15 06:45 0.50 INTRM1 DRILL CIRC P 6,862.0 6,862.0 Pump a dry job. Blow down the top drive. 06:45 12:00 5.25 INTRM1 DRILL TRIP P 6,862.0 659.0 Continue to POOH f/ 6,862' MD to 659' MD 12:00 12:45 0.75 INTRM1 DRILL PULD P 659.0 0.0 Monitor well 20 min, Hold PJSM while monitoring on BHA. Rack back HWDP, Jars. Lay down flex collars, stabilizers and bit. 12:45 14:00 1.25 INTRM1 DRILL RURD P 0.0 0.0 Flush stack, Pull wear ring, Clear and clean floor 14:00 15:30 1.50 INTRM1 RIGMNT SLPC P 0.0 0.0 Slip and cut 78' drill line. (Sim ops- change upper rams to 7 ") 15:30 16:15 0.75 INTRM1 WHDBOP BOPE P 0.0 0.0 Test upper 7" rams 250 psi low - 3,500 psi high 5 miinute per test. Rig down test equipment. Set 10 -3/8" wear ring. 16:15 18:15 2.00 INTRM1 CASING RURD P 0.0 0.0 PJSM, Rig up to run 7" casing. 18:15 23:00 4.75 INTRM1 CASING RNCS P 0.0 2,640.0 Run 7" casing per detail, Baker lok float equipment, Fill and check floats, (Floats good) Run 64 joints casing to 2640' MD up wt 90k dn wt 86k 23:00 00:00 1.00 INTRM1 CASING CIRC P 2,640.0 2,640.0 Circulate casing volume at 2,640' (Shoe) Stage pumps up slowly to 5 bpm 375 psi final circulating pressure. Mud Check Data MR f ato Geki(10s) Gel'(10rn) Gel (SOm) HTHP Filt DensityTemp Solids, Corr. Type Depth (ftKB) Dens (Ib /gal) Vis (slat) PV Cale (ep) (Ibf /10Qft') (Ibf /100fti (■bf /1OOft (Ibf1100ff') MaT' °(Ib /bbi)= (mL /3Omin) pH ( °F) :,( ° %) Glydril 8,879.0 10.40 9.0 11.0 13.000 15.0 6.4 9.0 93.0 Glydril 8,879.0 10.40 10.0 12.0 13.000 17.5 6.3 9.1 94.0 Injectlan Turd -_ - . Fluid ?; Source From Lease (bbi) = Vendor Manifest Number Note - Truck Rinsate CD3 -199 200.0 CD1 -19 AES 307398 =Wellbores Wellbore Name Wellbore API /UWI CD3 -199 501032063500 Section Size (in) Rck o (ftKD) Act Btm (ftKB)'', - Start Date ,° Ent Date SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Casing S trings k, StrinGOD String V •:, Casing t3ascnptiort ' C ' Run Date f f-„": fin) (Ibs/ft)" String Grade'; Set Depth (ftKB) .; `Comment illetSPF INTERMEDIATE 2/22/2011 7 26.00 L -80 8,870.0 Page 2/2 Report Printed: 2/20/2012 Security Level: AK Development PI I 'i,I'hl'ju r, Daily Drilling Report 'i,''I z irsii w ulIII t q ii , `I ' ll 0 � h CD3 -199 Gc�Phitj ➢p5 tail �ll� Report Number: 17 Rig: DOYON 141 Report Date: 2/23/2011 ",AEE;Type NetworkklDi* Ttltat,AFE +Sup " 10296871 7,774,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 199 Development FIORD NECHELIK 16.08 17.0 0.00 8,879.0 8,879.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,083.51 486,411.68 137,579.27 3,506,876.42 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/7/2011 2/7/2011 25.70 28.18 - 2.48 3/7/2011 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 8,870.0ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5" drillpipe Lay down 5" drillpipe, Pick up 4" drillpipe Last 24hr Summary Run 7" casing from 2,640' and to 8,869'. Circulated and conditioned at 4,830' md, 7,016' and and on bottom 8,869' md. Circulating rates staged up from 1 bpm to 5 bpm with final circulating pressure 400 psi. held PJSM, Pressure tested lines, performed 2 stage cement job, 1st stage cement job CIP @ 18:57 2nd stage cement job CIP @ 21:09. Rigged down from cement job. Pulled landing joint, drained stack, set and tested 7" packoff to 5,000 psi. Pressure test witnessed by rig supervisor. Cleared and cleaned floor in preparation for laying down 5" drillpipe. General Remarks Weather Head Count No Incidents, No Accidents. Rig on Hi -line. 22° Wind South @ 26 MPH Wind Chill 4° 46.0 Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Mark Brouillet, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer Drilling Engineer Time Log Start End. Dur Time Depth Stark Depth End Time Time thrs) Phase Op Code Activity Code P -T -X', TrhV Code Trb6Class. (MKS) <= (ftKB) Operation 00:00 03:15 3.25 INTRM1 CASING RNCS P 2,640.0 4,830.0 Run 7" casing f/2,640' and - t/ 4,830' md. Obtain up and down weight every 10 joints. 03:15 04:30 1.25 INTRM1 CASING CIRC P 4,830.0 4,830.0 Circulate and condition mud. Very thick dehydrated mud. Mud weight out 10.7 ppg. Lower mud weight to 10.4 ppg. Initial circulating rate 2 bpm - 300 psi, final circulating rate 5 bpm - 450 psi. Circulated over surface to surface volume. up wt 135k down wt 105k 04:30 07:45 3.25 INTRM1 CASING RNCS P 4,830.0 7,016.0 Run 7" casing f/4,830' and - t/ 7,016' md. Obtain up and down weight every 10 joints. 07:45 09:30 1.75 INTRM1 CASING CIRC P 7,016.0 7,016.0 Circulate and condition mud, Break circulation at 2.5 bpm - 350 psi, stage pumps up to 5 bpm - 500 psi. Final circulating pressure at 5 bpm - 450 psi. 09:30 12:15 2.75 INTRM1 CASING RNCS P 7,016.0 8,869.0 Complete running 7" casing, make up landing joint. Total joints run 214. Casing depth 8,869' md. 12:15 12:45 0.50 INTRM1 CEMENT RURD P 8,869.0 8,869.0 Rig down casing tongs, remove slips, rig down Franks fill up tool, Blow down top drive. Rig up cement head. 12:45 17:00 4.25 INTRM1 CEMENT CIRC P 8,869.0 8,869.0 Circulate and condition mud for cement job. Initial circulating rate 1 bpm - 250 psi final circulating rate 5 bpm - 600 psi. Rate staged up 1/2 bpm until final circulating rate reached. Final circulating pressure at 5 bpm - 400 psi. Up wt 245k • do wt 145k. (PJSM for cementing held while circulating.) Latest BOP Test Data 2/11/2011 Witness of test by AOGCC inspector Bob Noble. Page 1/3 Report Printed: 2/20/2012 � Il . 11llilllll l � Security Level: AK Development ACV x Daily Drilling Report Olig i -011 jjIW,il CD3 -199 CnacPhlilp Report Number: 17 Rig: DOYON 141 Report Date: 2/23/2011 Time Log $Cart End Dur Time Depth Start Depth End '= Time," Time (hrs) Phase Op Cede Activity Code l P4T -x " , Trbt Code Tibl'', Class. (ftKB) `, (ftKB) Operation -- 17:00 19:15 2.25 INTRM1 CEMENT CMNT P 8,869.0 8,869.0 Pump surface volume CW100 pressure test cement line to 3,500 psi, Continue pumping CW100, Drop top plug 25 bbl's CW100 pumped, Pump 5 bbl's CW100 total CW100 pumped 30 bbl's. batch and pump 27 bbl's 11.5 ppg Mudpush II spacer, Batch cement and pump 15.8 ppg lead slurry, volume pumped 53 bbl's. Shut down drop top plug chase with 20 bbl's water, Turn over to rig displace at 5 bpm bump plug at 3,104 strokes total mud pumped 314 bbl's. Casing reciprocated 20' stroke length throughout job up wt 245k do wt 145k, Casing landed on hanger with CIP @ 18:57. final circulating pressure 400 psi, Pressure up 700 psi over FCP held for 5 minutes, bled pressure off checked floats ( Floats Good) Pressure up to 3,400 psi to open stage collar at 5,324' md. 19:15 20:00 0.75 INTRM1 CEMENT CIRC P 8,869.0 8,869.0 Circulate and condition mud for 2nd stage cement job. @ 5 bpm - 300 psi, Increased rate to 6 bpm - 600 psi 20:00 21:15 1.25 INTRM1 CEMENT CMNT P 5,324.0 5,324.0 2nd stage cement job, Pump 30 bbl's pumped, Pump 28 bbl's 11.5 ppg Mudpush II spacer, Mix and pump 48 bbl's 15.5 ppg tail slurry, Drop top plug, Flush cement lines with water turn over to rig displace cement with 184 bbl's mud, Displace at 6 bpm - 270 psi, Bump plug with 1,790 strokes, Pressure up to 1,850 psi close stage collar, (Stage collar @ 5,324' md) pressure up to 2,300 psi hold for 5 minutes, bleed pressure confirm stage collar closed. CIP @ 21:09 21:15 00:00 2.75 INTRM1 CEMENT RURD P 0.0 0.0 Blow down lines, Rig down cement and casing equipment, lay down landing joint, Pull wear bushing, Install 7 packoff, Test packoff to 5,000 psi for 10 minutes, Test witnessed by Conoco rep. Lay down long bales, Prep floor to lay down 5" drillpipe. Mud Check Data YP Catc Get (10s)- (Ge (`lOn) ` Gel (30m) : f7ena4Cy Temp 11,8011040011 Type Depth (ftKB) Dena', (Ib/ga4). V (skit) PV Caic (cp) (Ibf/1 Q - (Ibf1100n (1bf11 QOff (Ibf /100rtx) FAST (Ib /bbt mLf3t]mirr)' .. _ pH'`. . ( ° FJ f /aj Glydril 8,879.0 10.40 10.0 12.0 14.000 18.7 6.2 9.0 97.0 Glydril 8,879.0 10.40 7.0 8.0 9.000 18.7 6.3 9.0 94.0 Injectibr► Eltdd = Fluid -_ _ Source From Lease(bbi) 'Destination - ManifestNumber Nate Cement Rinsate CD3 -199 170.0 CD1 -19 AES 348906 Cuttings CD3 -199 6.0 CD1 -19 AES 348904 Drilling Mud WBM CD3 -199 290.0 CD1 -19 AES 348905 Drilling Mud WBM CD3 -199 280.0 CD1 -19 AES 348902 Drilling Mud WBM CD3 -199 270.0 CD1 -19 AES 348907 Page 2/3 Report Printed: 2/20 /2012 GI Security Level: AK Development R t o �i� 4I � I II lilt IgI�m tGt ll "� ' �u l I'1 4 Daily Drilling Report ,'i��'9'�lh''Ill I CD3 -199 11 1' 1 ' Report Number: 17 Cn p' oocoPhillips Rig: DOYON 141 Report Date: 2/23/2011 Injection Fluid . . Fluid Source From Lease (bbl)_ - Destination ' Vender _ -,- Manifest Number `- Note - _: i == Drilling Mud WBM CD3 -199 265.0 CD1 -19 AES 348903 Drilling Mud WBM CD3 -199 130.0 CD1 -19 AES 307399 Truck Rinsate CD3 -199 200.0 CD1 -19 AES 348908 Wellbores Welibore Name Welibore API /UWI CD3 -199 501032063500 Section Size (in) Act Top (ftKB) - Act Btm (ftKB)',•;: Start Date End Date SURFAC 12 1/4 0.0 2,673.0 2/7/2011 2/9/2011 INTRM1 8 3/4 2,673.0 8,879.0 2/12/2011 2/19/2011 PROD1 6 1/8 8,879.0 15,742.0 2/28/2011 3/6/2011 Cement -= 7' Intermediate casing - Started A 2/23 /2011 Type Welibore Cemented String Cement Evaluation Results casing CD3 - 199 INTERMEDIATE, 8,870.0ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 7" Intermediate casing 7,810.0 8,879.0 5 400.0 Fluid" Class Amount (sacks) ' V (bbl) Density (tb/gal) Yield (fN /sack) ' Est;Top;(ftKB)' Est Btrn (ftKB) Intermediate Cement G 215 53.0 15.8 1.16 8,867.0 7,810.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 7" Intermediate casing 4,285.0 5,325.0 6 270.0 Fluid Class Amount (sacks) r V (bbl) ;_- Density (1b /gal) Yield (ft° /sack) Est, Top (ftKB) = " Est Btm =(ftKB) Intermediate Cement G 186 48.0 15.80 1.16 4,285.0 5,324.0 Page 3/3 Report Printed: 2/20 /2012 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 199 Rig: DO YON 141 D I 2/24/2011 I Volume Input Pump Rate: Drilling Supervisor: I Fred Herbert/ Mark Brcuillet Pump used: #2 Mud Pump Barrels Bbls /Strk ■.5t Bbl /min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy II Pumping down annulus and DP. Casing Test Pressure Integrity Test Hole Size: 8 -3/4" v Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 24.9IFt 2662.OIFt -MDI 2457.OIFt -TVD 4285.OIFt -MD 13685.OIFt -TVD Bbls psi Min psi Bbls psi Min psi Casino Size and Description: 7 26 # /Ft J -55 BTC -MOD 0 ;; 0 0 0.00 568 Changes for Annular Adequacy Test Pressure IntegritvTest 1 0.2 155 0.25 563 Enter outer casing shoe test results in comments Mud Weight: 10.4 ppg 2 0.41 174 0.501 563 Casing description references outer casing string. Inner casing OD: 7.0 In. ; :; :; ; :;:,:.:: 3 ::H 0.6 215 1.00 558 Hole Size is that drilled below outer casing. 4 ;;;;;;; 0.8 256 1.50 558 Use estimated TOC for Hole Depth. 5 ''' : 1 293 2.00 554 Enter inner casing OD at right. Desired PIT EMW: , ;;;;;;;;;;;; ppg 6 1.2 325 2.50 554 Estimates for Test: -1329 psi -0.1 bbls '::::::::::: 7 1.4 359 3.00 554 • v 8 ' : ' : 1.6 389 3.50 549 EMW = Leak -off Pressure + Mud Weight = 674 + 10.4 PIT 15 Second 9 ;;;;;;; 1.8 412 4.00 549 0.052 x TVD 0.052 x 2457 Shut -in Pressure, psi :::::' 10 2 444 4.50 549 EMW at 2662 Ft -MD (2457 Ft -TVD) = 15.7 563 15 2.2 467 5.00 549 1000 - - 1 20 ::::::::::::: 2.4 494 5.50 545 25::...:::: 2.6 526 6.00 545 30 2.8 545 6.50 545 3 577 7.00 545 3.2 604 7.50 545 3.4 627 8.00 540 3.6 645 8.50 540 o: 3.8 674 9.00 540 N 500 4 668 9.50 540 co 4.2 623 10.00 540 a 5 613 6 600 7 604 o .. 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Volume Volume Volume Volume Barrels Shut -In time, Mi nutes ...dr.-CASING TEST -• • LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls :...:IBbls 7.0 Bbls 1Bbls Comments: t..v3- 19 , Injec lvIty Test 2-44 -zu I I .XIS Summary • • • • TOM and Shannon, You. have requested tp di'spote of "new- product" c san up fluids from the routine mixing of. nud and cement..at Alpine as well as the clean up fluids resulting from • cleaning out the tanks at the. mud olant in preparation for using .oil base amd. The Commission had previously approved disposing Of the 'new product' clean up • fluids via annular disposal at CD 1 pad: . Due to they geological setting_ at Alpine, Class 1 and class 2 disposal options are. limited.. Phillips' prrdpeessor, ARCO, had eetablisYied the limitation of d .a ygca1 option. to the Cor i_ssipn's satisfaction ancl..annular disposal was - approved as cha practical and environmental alternative. It these requests the waste fluids are no different than previously approved and. . are the result of the..bncgoing develooMerit activities at Alpine. • The Cammissioners have authorized me to send You thin meserage.. By copy of this' email, Phillips is authorized to dispose of clean ixp fluids as described in your email. • Please call with any guestions- Porn Maunder, PE Sr. Petroleum Engineer • OGCC • `. ALP 'Env COOT i wrote.; • Dear Mr. Maunder, As noted in the •a.etached email, Tom Manson previously requested • a.uchoxization tc> .dispose• of new- product clean up fluids such. as cement } ri± sate, and mud., and trite pit rinses from' mixing operations via annular • injec;tlen in permttted, wears at the Alpine cD2 Drill Site, AS noted below, • 1+OGCC approved auoh disposal at the' CD1 Drill Site in 1999, based on the > integral relationship of the mud mixing I cility and the on -site drilling > operation. • Phillips would like to continuing pureui.nq this requests. Significant clean. • nut of tOlcs at thr :mud mixing facility mist oodur .in. prep'arati.on for the. temporary use of. oil bayed mud products at Alpine in. t.he• coming months: • The availability of annular disposal as an option for tank rinse fluids and > similar wastes would c reatly faci.lit,ate this process. (Typically, routine > rinses aro beneficially reut3r?d•, however, there is a concern about tt o potential quantity of fluid that'cbuia be generated during this large Scale > cleat up process.) a > Tanks at the mud mixing facility inay'contain either new and used mud products. Though rinses in contact with used products may be injected in > the permitted class IX disposal. well, (0:1$ rinses ..of new products would • pos.enLially he 1 Qutecl. to the class'. z dignosal• well (WD -O2} , where there is > a. difficulty managing solids content. The orris 1 r 11 is a critical :- lifeline for facility infrettructure, being the. disposal location for all. > domestic effluent, and it is a priority to prevent 'airy compromise to this • > disposal facility. Annular disposal presents a preferred waste management > alternative in this case. • • ( > Thank you very Much for Your ounsideratiOn a this reqUeSt. Please do not > hesitate to contact Me or MY alternate VA.& email, or phone at (907} 670-4200 > if you have questions or need addiaonal information. > • Shannon Dannelly • > Alpine PieldEnvironmental CoordinatOr • (907) 67p-d2oo Forwarded by'ALP Env Coord/PPCO on. 11/02/01 •12:50 Fff > ALP Env Cord 08/31/01 12.;45 PM > To; : t1.0„,maUndergadMin.state,ak.ua cc Request to inject Cement Rinsacs at CD2 . > Dear Mr. Maunder,. > Indeation of cement rinsate and clean-up' fluids from mud and brine mixing > operations at the Alpine mud plant facility into approved annular disposal > operations was . granted by Alaska 011 And Gas Conservation Commission > (ADGCC) in the'March 17,‘ 199 letter from AOGCC to DOug'Chester of ARCO > Alaska, inc, now Phi1Lip Al'aoka, Inc, (PA.1) . .The approval wee granted.= • sp6aifiCally Alpine Drill site CDl and authorized Volumes up to > 300 barrels through the annular saace. > > PA/ request that this approval be extended to drilling operations at Alpine. > Drill Site CD2. dement mixing operations for setting surface conduCtars > will be taking placaat the Grind.and Inject facility which. is currently > attached to .the drilling rig t. CD2, Upon c�mPletion of the cementing in > of the canductots, the lines and tank will have to be rinsed and the > rinsate disposed of. PAT request approval to inject this r•nsata, and > other .clean-up from the mud and brine mixing =orations, into the annual > spape.of approVed'Wells Located at Drill gild CD2. > you have any qUestions please contact me at 670-4200. ›. Tor xanson >. Alpine Field Environmental Compliance 5 torn_trauttier.vcf • • • • Ili D, Li t f \ , fi r- G r�qq _ i !,--,\ ( .r ,,r .:, -- ) r i r , 4 i C k 69 " ■ r _ / SEAN PARNELL, GOVERNOR k G �i P a �Ji p N k r R f C " d ALASKA OIL AND GA.S CONSERVATION COMMISSION i 333 H RAGE, ALA A 9 9 100 ANCHORAGE, ALASKA 99501 -3539 l PHONE (907) 279 -1433 1 FAX (907) 276 -7542 Mr. Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -122 ConocoPhillips Alaska Inc. Permit No: 209 -153 Surface Location: 3998' FNL, 1088' FEL, SEC. 5, T12N, R5E, UM Bottomhole Location: 3848' FNL, 1280' FEL, SEC. 8, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 0 Daniel T. eamount, Jr. Chair DATED this i 1 day of December, 2009 cc: Department of Fish 86 Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. • • .E EIVE i'/ 2 0 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '1b n' KG. ,la ' COi1.CUtCI�)a PERMIT TO DRILL Anchorage 20 AAC 25.005 - 1 a. Type of Work: 1b. Proposed Well Class: Development - Oil 5 - Service - Winj ❑ Single Zone IN lc. Specify if well is proposed for: Drill 5 • Re -drill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: LJ Blanket ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • CD3 - 122 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 15364' • TVD: 7074' • Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): 3998' FNL, 1088' FEL. Sec. 5. T12N, R5E, UM ADL 372105, 3 Fiord Oil Pool Top of Productive Horizon: 8. Land Use Permit: /I'. yr.c31 13. Approximate Spud Date: 4313' FNL, 4833' FEL. Sec. 5, T12N, R5E. UM LAS2112 1/9/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3848' FNL. 1280' FEL, Sec, 8. T12N, R5E, UM 2560 +1 1.8 miles to Eastern CRU Boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 49.1 feel 15. Distance to Nearest Well Opery GL El above MSL: • 12 feet !/` � C f y '�p 1 C^ Surface: x- 387954.5 T 6003779.7 Zone- 4 to Same Pool: CD3 - A, 037 ft /( 16. Deviated wells: Kickoff depth: 400 - ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.9° deg Downhole: 3201 psig . Surface: 2494 psig • 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) 24" 16" 62.5 H -40 Welded 77 37 37 114 114 Pre Installed 12.25" 9.625" 40 L -80 BTC 2774 37 37 2811 . 2500 ■ 513 sx AS Lite 3, 230 sx 15.8 'G' 8.75" 7" 26 L -80 BTC -M 8 37 37 � � 69 q �1 1st - 216 sx 15.8 'G' 2nd - 185 sx 15.8 G 3.5" 9.3 L -80 EUE ii' 32 32 35264 ` i Tubing 6.125" 3.5" 9.3 L -80 IBT -M 4B8' 3b ' [ -.3'2" -.3'2" -.3'2" 15340 7074 Liner with Baker Frac Point system y cJ q 0 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 5 Time v. Depth Plot ❑ Shallow Hazard Analysis 5 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 5 20 AAC 25.050 requirements 5 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Robertson - 265.6318 Printed Name /t Chip Alvord Title Alaska Drilling Manager Signature / .( O ( Phone 265 -6120 Date P/l L Y .. ( (-' "I /� �%""` Commission Use Only Permit to Drill API Number: / -, Permit Approval See cover letter Number: ;'97 �� /0 'D 5 � 50- � - �-l__ /�r Date: Ifo Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coal / 49 / (1 ed m ane, gas hydrates, or gas contained in shales: 4 3500 ,o 'S 8 P e S (-- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No L� Other: 2S measures: Yes ❑ No d Directional svy req'd: Yes , No [1 g 25 1OS� 4th- l- -r e - 5 f c " w.:4.... / • D rv�r fa" a i ✓L. z o t1/4 5.0 3 5 Ck. )Lz) APPROVED BY THE COMMISSION , COMMISSIONER / ' { Z-7// DATE: Form 10 - 401 (Revised 7/2009) This permit is valid f 2 h fq t e Q df ap royal (20 AAC 25.005(8)) Submit in D plicate ,mac /!/1��5' • • CD3 -122 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 -1/4" Hole / 9 -5/8" Casin • Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increase mud weight, decreased mud viscosity, increase circulating times, control drilling rates and low mud temperatures Running Sands and Gravel , Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight to 9.6 — 9.8 pp Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM pills and use of low density cement slurries 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight above 9.6 ppg. Flow Surface Formations • checks during connections. Mud weight increase if >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use - standard well control practices. Employ mud scavengers. 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 8.8 ppg. • Pressure Check for flow during connections and if needed, increase mud weight. Perform well control drills. Increase mud weight if needed. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use standard well control practices. Employ mud scaiegrA OR ...31 Riq Procedure 1. Move rig onto CD3 -122. 2. Rig up riser. 3. Drill 12 -1/4" hole to surface casing point as per the directional plan (Directional /MWD) • 4. Run and cement 9 -5/8" surface casing. 5. Install BOPE and test to 3,500 psi. 6. Pressure test casing to 2,500 psi. 7. Drill out 20' of new hole and perform leak off test. 8. Pick up and run in the hole with 8 -3/4" drilling BHA. 9. Drill 8 -3/4" hole to intermediate casing point into the Nechelik reservoir sand (GR /RES /PWD). 10. Run and cement 7" casing as per drilling program. Perform a leak off test down the 9 -5/8" x 7" annulus to confirm the fracture pressure referenced to the surface casing shoe. If needed, a second stage cement job will be pumped to isolate the K2 (Qannik) formation. 11. Freeze protect the casing annulus to surface. 12. Perform BOPE test to 3,500 psi. 13. Pick up and run 6 -1/8" drilling BHA. 14. Pressure test 7" intermediate casing to 3,500 psi. 15. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 16. Displace well to Flo -Thru mud system. 17. Drill 6 -1/8" horizontal section to well TD (LWD Program: DENS /NEUT /GR/RES /PWD) 18. Circulate hole clean and pull out of hole. 19. Run and set Baker Frac Point system lower completion: ZXP liner top hanger, Flex lock liner hanger, 3 -1/2 ", 9.3 ppf, L -80 tubing with 6 x ball actuated sleeves and 5 x swell packers. 20. Run upper completion: 3 -1/2 ", 9.3 ppf, L -80 tubing with SSSV, gas lift mandrels, packer, XN nipple and seal bore assembly. Sting in, space out and land hanger. 21. Install two way check valve and pressure test hanger seals to 5,000 psi. 22. Nipple down BOP 23. Install tubing head adapter assembly. 24. Pressure test adapter assembly to 5,000 psi. 25. Remove two way check valve. 26. Circulate tubing to diesel and install freeze protection in the annulus. 27. Install BPV and secure well. 28. Move rig off CD3 -122. �1?�� to A �_ • WELL PROXIMITY RISKS Directional drilling and collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3 -118 is the nearest existing well to the CD3 -122 plan with 18' well to well separation at 1,037' MD. DRILLING AREA RISKS There are no high risk events anticipated. ' No over pressured zones are expected. Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. ANNULAR PUMPING OPERATIONS: Incidental fluids developed from drilling operations on well CD3 -122 will be injected into a permitted annulus on the CD3 pad, or the class 1 disposal well on CD1 pad. The CD3 -122 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 -122 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10 -403 would 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) * (Surface Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,500') + 1,500 psi = 3,060 psi Pore Pressure = 1,131 psi Therefore Differential = 3,060 psi — 1,131 psi = 1929 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9 -5/8" 40 L -80 3 BTC 9,090 psi 7,727 psi 5,750 psi 4,888 psi 7" 26 L -80 3 BTC -Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi • 1 DRILLING FLUID PROGRAM SPUD to 9 -5/8" Intermediate hole to 7" Production Hole surface casing point casing point — 8 3/4" Section — 6 1/8" — 12 1/4" Density 8.7 — 9.8 ppg 9.6 — 9.8 ppg 9.0 ppg PV 10 — 16 7 —12 YP 30 -60 13 -16 10 -15 Funnel Viscosity 70 — 300 Initial Gels 8 — 10 6 - 9 10 minute gels <20 8 - 12 API Filtrate NC — 10 cc / 30 min 5 — 12 cc /30 min (drilling) HPHT Fluid Loss at 10 cc /30 min 165 8.5 -9.0 9.0 -10.0 9.0 -9.5 PH 3% KCL Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec /qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80 -100 sec /qt. Mud weight will be maintained at < 9.8 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo -Thru drill -in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. O R G N! \ L Alpine - CD3 -122 Nechelik Producer Upper Completion MD TVD Lower Completion MQ Dm 1) Tubing Hanger 32' 32' 16) Baker 5" X 7" Flex Lock Hanger and ZXP Liner Top Packer 9200' 6935' ' 16" Conductor to 114' 2) 4 -1/2 ", 12.6 # /ft, IBT -Mod Tubing (2 jts) w/ Sealbore 3) Crossover 4 -1/2 x 3 -1/2 17) XO 5" BTC X 3.5" IBT -Mod 9234' 6940' 4) 3 -1/2" Camco TRMAXX -5E SSSV (2.812" ID) 2200' 2070' 18) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 9236' 6940' 5) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 19) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 9833' 6966' 6) 3 -1/2" Camco KBMG -GLM w/ DV 4100' 3400' Wire wrapped screen and Resman Tracer 7) 3 -1/2' 9.3 # /ft, EUE -Mod Tubing 20) 3 '/ Baker Ball Actuated Sleeve (2.150" Seat ID) 9863' 6967' 3-1/2" Camco KBMG -GLM w/ DV 7250' 5600' 21) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 9878' 6968' 8 9 -5/8" 36 ppf J -55 BTC 8) Wire wrapped screen and Resman Tracer 3 -1/2', 9.3 # /ft, EUE -Mod Tubing 22) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 9898' 6968' i; iii at 2,811' MD / 2,500' TVD 10) 3 -1/2" Camco KBMG GLM w/ DCK2 Shear 8799 6812 23) Swell Packer (344 ) OD 5 -3/4 10361' 6979' Cemented to Surface Set @2500psi 24) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 10376' 6980' 4 hl 11) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing (2 Jts) 8806' 6812' 25) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 10829' 6990' 12) 3 -1/2 ", "D" at 66° inc 8866' 6845' Wre wrapped screen and Resman Tracer 13) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 8868' 6846' 26) 3-% Baker Ball Actuated Sleeve (2.025" Seat ID) 10859' 6991' 3 -1/2" 9.3 ppf L -80 EUE 14) 3 -1/2 ", 9.3 # /ft, EUE -Mod 10' pup joint 9188 6933' 27) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 10874' 6991' Tubing 15) Seal Assembly (17' of seals) 9198' 6935' Wre wrapped screen and Resman Tracer g and half mule shoe stung in X (TBD) below 9200' 6935' 28) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 10894' 6991' Ill Liner Hanger 29) Swell Packer (3 -%) OD 5-3/4 11357' 7001' GL E l 30) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 11372' 7001' TOC = +/- 4,525' MD / 31) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 11825' 7011' +/- 3,700' TVD Wire wrapped screen and Resman Tracer 32) 3 -14 Baker Ball Actuated Sleeve (1.900" Seat ID) 11855' 7011' Qannik Interval 33) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 11870' T011' III, HI, To +/- 5,025' MD / 4,049' TVD To wrapped screen and Resman Tracer p 34) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 11890' 7012' Base +/- 5,054' MD / 4,069' TVD 35) Swell Packer (3 -14) OD 5 -% 12353' 7020' Stage Collar 36) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 12368' 7022' +/- 5,554 MD / 4,419' TVD 37) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 12821' 7030' Wire wrapped screen and Resman Tracer G) 38) 3-% Baker Ball Actuated Sleeve (1.775" Seat ID) 12851' 7030' 39) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 12866' 7031' Wire wrapped screen and Resman Tracer . . 40) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 12886' 7032' 41) Swell Packer (3-% ) OD 5 -54 13349' 7039' 42) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 13364' 7040' 43) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 13817' 7048' j Wire wrapped screen and Resman Tracer GL 44) 3 -14 Baker Ball Actuated Sleeve (1.650" Seat ID) 13847' 7049' • 45) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 13862' 7049' Wire wrapped screen and Resman Tracer 46) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 13882' 7050' 47) Swell Packer (3 - '/) OD 5 -3/4 14345' 7058' 48) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 14360' 7058' 49) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 14813' 7066' Wre wrapped screen and Resman Tracer 50) 3 -% Baker Ball Actuated Sleeve (1.525" Seat ID) 14843' 7066' 51) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 20' pup joint w/ 12' of 14858' 7066' Wire wrapped screen and Resman Tracer 7" 26 ppf L -80 BTC -M 52) 3 -1/2 ", 9.3 # /ft, IBT -Mod Tubing 14878' 7067' . '":,:i,, Production Casing 53) Float Shoe 15340' 7074' TOC +/- 8,256' at 9 = 6 TVD @ +/- 88 TD 6 1/8 hole @ 3 -1/2" 9.3 ppf L -80 IBT -Mod MD / 6,434' TVD Tubing 15,364' MD / 7074' TVD . . 23 29 35 41 Top of Kuparuk 8,756' MD / 6,792' .I 20 = 26 1111 32 38 , 44 iii 50 III TVD L 15 1i� 1i, .® 1 :, 1i, 1. 4: 1 Top of Nechelik i 9,227' MD / 6,939' .! 19 S 25 II 31 33 • 16 21 27 ■ CD O ■ EDO • 49 51 TVD • CD3 -115 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD /TVD(ft) (ppg) (psi) (psi) 16" ' 114 / 114 10.9 52 53 9 -5/8" *2'5/ ..28 2500 • 14.5 1131 1635 7" ip 9365 / 6951 16.0 3145 2494 N/A , /t.; 15364 / 7074 16.0 3201 , N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi /ft 0.1 = Gas gradient in psi /ft D = True vertical depth of casing seat in ft RKB OR 2) ASP =FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 114 = 53 psi OR ASP = FPP – (0.1 x D) = 1131 – (0.1 x 2500') = 881 psi 2. Drilling below surface casing (9 -5/8 ") 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) = 3145 – (0.1 x 6951') = 2449 psi 3. Drilling below intermediate casing (7 ") ASP = FPP – (0.1 x D) = 3201 – (0.1 x— = 2494 psi • . • Cementing Program: 9 5/8" Surface Casing run to 2881' MD / 2500' TVD. Cement from 2811' MD to 2311' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2381' to surface with 10.7 ppg Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1633' MD). Lead slurry: (2311'- 1529') X 0.3132 ft /ft X 1.5 (50% excess) = 367.2 ft below permafrost 1529' X 0.3132 ft /ft X 4 (300% excess) = 1915.6 ft above permafrost Total volume = 367.2 + 1915.6 = 2282.8 ft => 513 Sx @ 4.45 ft /sk System: 513 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft /sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW D044 freeze suppressant Tail slurry: (2811' - 2311') X 0.3132 ft /ft X 1.5 (50% excess) = 234.9 ft annular volume 80' X 0.4341 ft /ft = 34.7 ft shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft => 230 Sx @ 1.17 ft /sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft /sk 7" Intermediate Casing run to 9365' MD / 6951' TVD: Cemented in two stages Cement from 9365' MD to 8256' MD (300' MD above the packer & minimum 500' MD above top of Kuparuk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (9365' - 8256') X 0.1503 ft /ft X 1.4 (40% excess) = 233.4 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 233.4 + 17.2 = 250.6 ft => 216 Sx @ 1.16 ft /sk System: 216 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3 /sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik (K2) interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5554' - 4525') X 0.1503 ft /ft X 1.4 (40% excess) = 216.5 ft annular vol. Total Volume = 216.5 ft => 185 Sk @ 1.17 ft /sk System: 185 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft /sk ' By Weight Of mix Water, all other additives are BWOCement 9 CR A L • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fjord Pad Plan: CD3 -122 Plan: CD3 -122 Plan: CD3- 122wp03 Standard Proposal Report Permit 19 November, 2009 PaCK ( NA D 27 a Surface Location i s subject to change II i ■■ HALLIBURTON • • Sperry Drilling Services ORIGINAL . • Western IJ North Slope CD3- 122wp03 HALLIBRTON I.' CD3 Fiord d Pad ConocoPhillips Plan: CD3 -122 Sperry Drilling Plan: CD3 -122 CD3- 122wp03 D D I : 6.722 SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 2000- 36.30 1000.00 CD3- 122wp03 (Plan: CD3 -122) GYD -CT -CMS I 1000.00 15363.81 CD3- 122wp03 (Plan: CD3 -122) MWD +IFR- AK- CAZ -SC co N c C = 0 � O - OO i CD3- 113_SouthwpXX Top Nechelik i + o -2000 - Z . 0 to -4000 - CP CD3- 113_SouthwpXX Toe I I -6000 -4000 -2000 0 2000 4000 West( -) /East( +) (2000 ft /in) CASING DETAILS TVD MD Name Size 2500.00 2810.61 9 -5/8" x 12 -1/4" 9 -5/8 0 6951.10 9365.04 7 x 8 -3/4" 7 7074.10 15363.81 4 -1/2" x 6 -1/8" 4 -1/2 c co co C -20 2500 ‘ Q K -3 K -3 Basal CI) vo. CI U K -2 Basal K 2 co 0 • 5000 A lbian 97 Albian 96 N w - 2-9° L Top HRZ Base HRZK 1 80 0 H T _--- op Kuparuk D co 1 U __- Top Kuparuk C -- - - Base Nechelio Nechelik �p NuigsutLCU CD3- 113_SouthwpXX Top Neche CD3 -113 SouthwpXX Toe ■ 750 Base Nui s -7500 p -000 -2500 0 2500 5000 7500 Vertical Section at 143 00° (2500 ft/in) ORIGINAL Easting (3500 ft/in) I I I I I I I I I Iii I , I i i i 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1, 1 1 1 1 1 1 I I I I I I I I I I I I I I I I l l I I , I I I I I l I I I) l I I I I I I rn l,. ConocoPhillips(Alaska) Inc. -WNS ` ° " Western North Slope U:00, * , ' CD3 Fiord Pad ' – CD3- 126wp02 C a33 1 wp04 (fail- A @p-125w - CD3 -108 - - CD3 -110 CD3 -1 L1 - C r 1L1 - CD3 -1 CD3-111 CD "0 A wp05 f€111130■16 • CD3 -11 ' CD3 -' 02Awp1.' - CD3 -1 a - - CD3 - - - - D3 -1 5 / . r_..f�i2p6 - a ,��,j]f CD3 -1 . CD3-307 = u2 01 c - CD3 -124 , IQA33 -1 ► . -302 - :1 = o r -- _ �� �, I l�, ON- I. A .: CD3 303 — . — D 316 C ! - 1 _ • :wp II CD3 -199w p 01 ∎ CD3 -12e ` . r 4 119w. = CD3-121wp02 _ CD3 -31 – CD3-305F CD3- 122wp03 - = CD3- 123wp02 CD3 -3c15 , I I ,, I I I 1 1 I I I 1 I 1 I I ,, 1 I I I 1,, I , 1 1 1 1 1 1 1, 1 1 1 I 1 I I I I 1 1 1 1 I, 1 ,,,, I ,, I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 Easting (3500 ft/in) • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 15 . Project: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 15 Site: CD3 Fjord Pad North Reference: True Well: Plan: CD3 - 122 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -122 Design: CD3- 122wp03 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 Fjord Pad Site Position: Northing: 469.98ft Latitude: 53° 58' 43.652 N From: Map Easting: - 401.25ft Longitude: 152° 19' 30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88 ° Well Plan: CD3 -122 _. - Well Position +N /-S O.00ft Northing: 6,003,779.67ft • Latitude: 70° 25' 9.348 N +E / -W 0.00 ft Easting: 387,954.53 ft • Longitude: 150° 54' 45.989 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft , Weilbore Plan: CD3 -122 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( (nT) L BGGM2007 11/18/2009 16.41 79.70 57,315 Design CD3 -122w 03 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +N /-S +E/ W Direction (ft) (ft) (ft) ( 36.30 0.00 0.00 143.00 Plan Sections j Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +EI-W Rate Rate Rate Tool Face (ft) ( ( (ft) ft (ft) (ft) ( °I100ft) ( °IlOOft) ( °/1OOft) ( °) 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 350.90 0.00 0.00 0.00 0.00 0.00 0.00 600.09 3.00 315.00 600.00 550.90 3.70 -3.70 1.50 1.50 0.00 315.00 1,106.53 14.13 318.95 1,100.00 1,050.90 59.89 -53.84 2.20 2.20 0.78 5.00 2,386.40 45.60 281.62 2,203.20 2,154.10 276.67 - 622.31 2.75 2.46 -2.92 -48.75 6,867.49 45.60 281.62 5,338.37 5,289.27 921.37 - 3,758.43 0.00 0.00 0.00 0.00 9,365.04 88.00 135.00 6,951.10 6,902.00 - 314.30 - 3,743.45 5.00 1.70 -5.87 - 137.91 10,420.64 88.75 144.29 6,981.10 6,932.00 - 1,117.52 - 3,060.97 0.88 0.07 0.88 85.52 15,363.81 89.09 144.29 7,074.10 7,025.00 - 5,130.54 - 176.21 0.01 0.01 0.00 -0.16 11/19/2009 9:00:58AM Page 2 COMPASS 2003.16 Build 69 Conoco Phillips • p HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19 Site: CD3 Fjord Pad North Reference: True Welk Plan: CD3 -122 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -122 Design: CD3- 122wp03 P lanned 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) -12.80 I 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 6,003,779.67 387,954.53 0.00 0.00 100.00 0.00 0.00 100.00 50.90 0.00 0.00 6,003,779.67 387,954.53 0.00 0.00 200.00 0.00 0.00 200.00 150.90 0.00 0.00 6,003,779.67 387,954.53 0.00 0.00 300.00 0.00 0.00 300.00 250.90 0.00 0.00 6,003,779.67 387,954.53 0.00 0.00 400.00 • 0.00 0.00 400.00 350.90 0.00 0.00 6,003,779.67 387,954.53 0.00 0.00 Start Build 1.50 500.00 1.50 315.00 499.99 450.89 0.93 -0.93 6,003,780.60 387,953.62 1.50 -1.30 600.00 3.00 315.00 599.91 550.81 3.70 -3.70 6,003,783.42 387,950.89 1.50 -5.18 600.09 3.00 315.00 600.00 550.90 3.70 -3.70 6,003,783.42 387,950.88 1.50 -5.19 Start DLS 2.20 TFO 5.00 700.00 5.19 317.12 699.65 650.55 8.87 -8.63 6,003,788.66 387,946.03 2.20 -12.28 800.00 7.39 317.98 799.04 749.94 16.97 -16.02 6,003,796.87 387,938.77 2.20 -23.19 900.00 9.59 318.45 897.94 848.84 27.98 -25.86 6,003.808.03 387,929.10 2.20 -37.91 1,000.00 11.79 318.74 996.19 947.09 41.90 -38.12 6,003,822.13 387,917.05 2.20 -56.40 1,100.00 13.99 318.94 1,093.67 1,044.57 58.70 -52.80 6,003,839.14 387,902.62 2.20 -78.65 1,106.53 14.13 318.95 1,100.00 1,050.90 59.89 -53.84 6,003,840.35 387,901.60 2.20 -80.23 Start DLS 2.75 TFO - 48.75 1,200.00 15.94 311.90 1,190.27 1,141.17 77.08 -70.89 6,003,857.79 387,884.81 2.75 - 104.22 1,300.00 18.08 305.97 1,285.90 1,236.80 95.37 -93.68 6,003,876.42 387,862.30 2.75 - 132.54 1,400.00 20.36 301.29 1,380.33 1,331.23 113.52 - 121.11 6,003,894.98 387,835.15 2.75 - 163.55 1,500.00 22.74 297.54 1,473.33 1,424.23 131.50 - 153.12 6,003,913.44 387,803.42 2.75 - 197.17 1,600.00 25.19 294.47 1,564.71 1,515.61 149.26 - 189.63 6,003,931.74 387,767.17 2.75 - 233.33 1,700.00 27.70 291.92 1,654.24 1,605.14 166.75 - 230.58 6,003,949.84 387.726.51 2.75 - 271.94 1,800.00 30.24 289.76 1,741.72 1,692.62 183.95 - 275.84 6,003,967.71 387,681.50 2.75 - 312.91 1,900.00 32.82 287.91 1,826.95 1,777.85 200.80 - 325.34 6,003,985.31 387,632.27 2.75 - 356.16 2,000.00 35.42 286.31 1,909.74 1,860.64 217.27 - 378.94 6,004,002.58 387,578.93 2.75 - 401.57 2,100.00 38.03 284.89 1,989.88 1,940.78 233.33 - 436.53 6,004,019.50 387,521.59 2.75 - 449.06 2,200.00 40.66 283.64 2,067.21 2,018.11 248.93 - 497.98 6,004,036.02 387,460.39 2.75 - 498.49 2,300.00 43.31 282.51 2,141.53 2,092.43 264.04 - 563.14 6,004,052.10 387,395.47 2.75 - 549.78 2,386.40 45.60 281.62 2,203.20 2,154.10 276.67 - 622.31 6,004,065.62 387,336.50 2.75 - 595.47 Start 4481.09 hold at 2386.40 MD 2,400.00 45.60 281.62 2,212.72 2,163.62 278.63 - 631.83 6,004,067.72 387,327.01 0.00 - 602.77 2,500.00 45.60 281.62 2,282.68 2,233.58 293.02 - 701.81 6,004,083.16 387,257.26 0.00 - 656.37 2,600.00 45.60 281.62 2,352.65 2,303.55 307.40 - 771.80 6,004,098.59 387,187.50 0.00 - 709.98 2,700.00 45.60 281.62 2,422.61 2,373.51 321.79 - 841.78 6,004,114.03 387,117.75 0.00 - 763.59 2,800.00 45.60 281.62 2,492.58 2,443.48 336.18 - 911.77 6,004,129.46 387,047.99 0.00 - 817.20 2,810.61 . 45.60 281.62 2,500.00 , 2,450.90 337.70 - 919.19 6,004,131.10 387,040.59 0.00 - 822.89 9 - 5 /8" x 12 2,900.00 45.60 281.62 2,562.54 2,513.44 350.56 - 981.75 6,004,144.89 386,978.23 0.00 - 870.81 3,000.00 45.60 281.62 2,632.50 2,583.40 364.95 - 1,051.74 6,004,160.33 386,908.48 0.00 - 924.42 3,100.00 45.60 281.62 2,702.47 2,653.37 379.34 - 1,121.73 6,004,175.76 386,838.72 0.00 - 978.02 3,200.00 45.60 281.62 2,772.43 2,723.33 393.73 - 1,191.71 6,004,191.20 386,768.97 0.00 - 1,031.63 3,300.00 45.60 281.62 2,842.40 2,793.30 408.11 - 1,261.70 6,004,206.63 386,699.21 0.00 - 1,085.24 3,346.74 45.60 281.62 2,875.10 2,826.00 414.84 - 1,294.41 6,004,213.85 386,666.61 0.00 - 1,110.30 C 11/19/2009 9:00:58AM Pane 3 COMPASS 2003.16 Build 69 , ,r.. L ` , ti' Li • ConocoPhillips HALLIBURT ®N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19 Project: Western North Slope MO Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 1 Site: CD3 Fjord Pad North Reference: True Welk Plan: CD3 -122 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -122 Design: CD3- 122wp03 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) ( °) ( (ft) ft (ft) (ft) (ft) (ft) 2,863.26 3,400.00 45.60 281.62 2,912.36 2,863.26 422.50 - 1,331.68 6,004,222.07 386,629.45 0.00 - 1,138.85 I 3,500.00 45.60 281.62 2,982.33 2,933.23 436.89 - 1,401.67 6,004,237.50 386,559.70 0.00 - 1,192.46 3,600.00 45.60 281.62 3,052.29 3,003.19 451.27 - 1,471.65 6,004,252.94 386,489.94 0.00 - 1,246.07 3,700.00 45.60 281.62 3,122.26 3,073.16 465.66 - 1,541.64 6,004,268.37 386,420.19 0.00 - 1,299.67 3,800.00 45.60 281.62 3,192.22 3,143.12 480.05 - 1,611.62 6,004,283.80 386,350.43 0.00 - 1,353.28 3,900.00 45.60 281.62 3,262.18 3,213.08 494.43 - 1,681.61 6,004,299.24 386,280.68 0.00 - 1,406.89 4,000.00 45.60 281.62 3,332.15 3,283.05 508.82 - 1,751.60 6,004,314.67 386,210.92 0.00 - 1,460.50 4,100.00 45.60 281.62 3,402.11 3,353.01 523.21 - 1,821.58 6,004,330.11 386,141.16 0.00 - 1,514.11 4,200.00 45.60 281.62 3,472.08 3,422.98 537.60 - 1,891.57 6,004,345.54 386,071.41 0.00 - 1,567.72 4,300.00 45.60 281.62 3,542.04 3,492.94 551.98 - 1,961.55 6,004,360.98 386,001.65 0.00 - 1,621.32 4,400.00 45.60 281.62 3,612.01 3,562.91 566.37 - 2,031.54 6,004,376.41 385,931.90 0.00 - 1,674.93 4,500.00 45.60 281.62 3,681.97 3,632.87 580.76 - 2,101.52 6,004,391.85 385,862.14 0.00 - 1,728.54 4,600.00 45.60 281.62 3,751.94 3,702.84 595.14 - 2,171.51 6,004,407.28 385,792.38 0.00 - 1,782.15 4,700.00 45.60 281.62 3,821.90 3,772.80 609.53 - 2,241.50 6,004,422.71 385,722.63 0.00 - 1,835.76 I 4,781.76 45.60 281.62 3,879.10 3,830.00 621.29 - 2,298.71 6,004,435.33 385,665.60 0.00 - 1,879.59 K ' 4,800.00 45.60 281.62 3,891.86 3,842.76 623.92 - 2,311.48 6,004,438.15 385,652.87 0.00 - 1,889.37 4,900.00 45.60 281.62 3,961.83 3,912.73 638.30 - 2,381.47 6,004,453.58 385,583.12 0.00 - 1,942.97 4,984.72 45.60 281.62 4,021.10 3,972.00 650.49 - 2,440.76 6,004,466.66 385,524.02 0.00 - 1,988.39 K Basal 5,000.00 45.60 281.62 4,031.79 3,982.69 652.69 - 2,451.45 6,004,469.02 385,513.36 0.00 - 1,996.58 5,024.74 45.60 281.62 4,049.10 4,000.00 656.25 - 2,468.76 6,004,472.84 385,496.11 0.00 - 2,009.84 K - 2 5,100.00 45.60 281.62 4,101.76 4,052.66 667.08 - 2,521.44 6,004,484.45 385,443.61 0.00 - 2,050.19 5,174.81 45.60 281.62 4,154.10 4,105.00 677.84 - 2,573.80 6,004,496.00 385,391.42 0.00 - 2,090.30 K - 2 Basal 5,200.00 45.60 281.62 4,171.72 4,122.62 681.46 - 2,591.42 6,004,499.89 385,373.85 0.00 - 2,103.80 5,300.00 45.60 281.62 4,241.69 4,192.59 695.85 - 2,661.41 6,004,515.32 385,304.09 0.00 - 2,157.41 5,400.00 45.60 281.62 4,311.65 4,262.55 710.24 - 2,731.40 6,004,530.76 385,234.34 0.00 - 2,211.02 5,500.00 45.60 281.62 4,381.62 4,332.52 724.63 - 2,801.38 6,004,546.19 385,164.58 0.00 - 2,264.62 5,600.00 45.60 281.62 4,451.58 4,402.48 739.01 - 2,871.37 6,004,561.63 385,094.83 0.00 - 2,318.23 5,700.00 45.60 281.62 4,521.54 4,472.44 753.40 - 2,941.35 6,004,577.06 385,025.07 0.00 - 2,371.84 5,800.00 45.60 281.62 4,591.51 4,542.41 767.79 - 3,011.34 6,004,592.49 384,955.31 0.00 - 2,425.45 5,900.00 45.60 281.62 4,661.47 4,612.37 782.17 - 3,081.32 6,004,607.93 384,885.56 0.00 - 2,479.06 6,000.00 45.60 281.62 4,731.44 4,682.34 796.56 - 3,151.31 6,004,623.36 384,815.80 0.00 - 2,532.67 6,100.00 45.60 281.62 4,801.40 4,752.30 810.95 - 3,221.29 6,004,638.80 384,746.05 0.00 - 2,586.28 6,200.00 45.60 281.62 4,871.37 4,822.27 825.33 - 3,291.28 6,004,654.23 384,676.29 0.00 - 2,639.88 6,300.00 45.60 281.62 4,941.33 4,892.23 839.72 - 3,361.27 6,004,669.67 384,606.54 0.00 - 2,693.49 6,400.00 45.60 281.62 5,011.30 4,962.20 854.11 - 3,431.25 6,004,685.10 384,536.78 0.00 - 2,747.10 6,500.00 45.60 281.62 5,081.26 5,032.16 868.50 - 3,501.24 6,004,700.54 384,467.02 0.00 - 2,800.71 6,600.00 45.60 281.62 5,151.22 5,102.12 882.88 - 3,571.22 6,004,715.97 384,397.27 0.00 - 2,854.32 6,700.00 45.60 281.62 5,221.19 5,172.09 897.27 - 3,641.21 6,004,731.40 384,327.51 0.00 - 2,907.93 6,800.00 45.60 281.62 5,291.15 5,242.05 911.66 - 3,711.19 6,004,746.84 384,257.76 0.00 - 2,961.53 6,867.49 45.60 281.62 5,338.37 5,289.27 921.37 - 3,758.43 6,004,757.26 384,210.68 0.00 - 2,997.71 Start DLS 5.00 TFO - 137.91 11/19/2009 9:00:58AM Page 4,„ 1 i ( COMPASS 2003.16 Build 69 0, i'L.'t 6' ‘ • ConocoPhillips HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19, Project: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 13 Site: CD3 Fjord Pad North Reference: True Well: Plan: CD3 -122 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3 -122 Design: CD3- 122wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +14I-S +51-W Northing Easting DLS Vert Section (ft) (°) ( °) (tt) ft (ft) (ft) (ft) (ft) 5,312.26 6,900.00 44.41 280.06 5,361.36 5,312.26 925.69 - 3,781.00 6,004,761.92 384,188.17 5.00 - 3,014.76 7,000.00 40.87 274.83 5,434.93 5,385.83 934.56 - 3,848.10 6,004,771.80 384,121.22 5.00 - 3,062.22 7,085.70 38.06 269.74 5,501.10 5,452.00 936.80 - 3,902.48 6,004,774.85 384,066.88 5.00 - 3,096.74 Albian 97 I 7,100.00 37.61 268.83 5,512.40 5,463.30 936.70 - 3,911.26 6,004,774.88 384,058.11 5.00 - 3,101.93 7,200.00 34.70 261.93 5,593.16 5,544.06 932.07 - 3,969.99 6,004,771.14 383,999.32 5.00 - 3,133.59 7,300.00 32.24 254.03 5,676.61 5,627.51 920.73 - 4,023.85 6,004,760.61 383,945.29 5.00 - 3,156.95 7,400.00 30.34 245.12 5,762.11 5,713.01 902.76 - 4,072.44 6,004,743.37 383,896.45 5.00 - 3,171.83 7,500.00 29.10 235.34 5,849.00 5,799.90 878.29 - 4,115.38 6,004,719.54 383,853.15 5.00 - 3,178.13 1 7,529.83 28.88 232.29 5,875.10 5,826.00 869.76 - 4,127.05 6,004,711.19 383,841.36 5.00 - 3,178.34 Aibian 96 7,600.00 28.62 225.02 5,936.64 5,887.54 847.51 - 4,152.35 6,004,689.32 383,815.73 5.00 - 3,175.79 7,700.00 28.93 214.64 6,024.34 5,975.24 810.65 - 4,183.05 6,004,652.94 383,784.47 5.00 - 3,164.84 7,800.00 30.02 204.71 6,111.45 6,062.35 768.00 - 4,207.27 6,004,610.66 383,759.62 5.00 - 3,145.35 7,900.00 31.79 195.59 6,197.30 6,148.20 719.88 - 4,224.82 6,004,562.81 383,741.36 5.00 - 3,117.48 8,000.00 34.14 187.48 6,281.24 6,232.14 666.65 - 4,235.55 6,004,509.75 383,729.82 5.00 - 3,081.43 8,100.00 36.96 180.37 6,362.62 6,313.52 608.73 - 4,239.40 6,004,451.90 383,725.11 5.00 - 3,037.49 I 8,200.00 40.16 174.19 6,440.84 6,391.74 546.54 - 4,236.33 6,004,389.68 383,727.24 5.00 - 2,985.98 8,300.00 43.64 168.81 6,515.28 6,466.18 480.57 - 4,226.37 6,004,323.57 383,736.22 5.00 - 2,927.29 ' 8,327.61 44.64 167.45 6,535.10 6,486.00 461.76 - 4,222.41 6,004,304.70 383,739.89 5.00 - 2,909.89 Top HRZ I 8,400.00 47.34 164.09 6,585.40 6,536.30 411.32 - 4,209.58 6,004,254.08 383,751.96 5.00 - 2,861.89 8,500.00 51.21 159.92 6,650.65 6,601.55 339.31 - 4,186.10 6,004,181.74 383,774.35 5.00 - 2,790.25 8,515.19 51.81 159.32 6,660.10 6,611.00 328.17 - 4,181.96 6,004,170.53 383,778.32 5.00 - 2,778.85 Base HRZ 8,592.27 54.90 156.45 6,706.10 6,657.00 270.90 - 4,158.66 6,004,112.93 383,800.76 5.00 - 2,719.10 K - 1 8,600.00 55.22 156.18 6,710.53 6,661.43 265.10 - 4,156.11 6,004,107.09 383,803.22 5.00 - 2,712.93 8,670.17 58.09 153.77 6,749.10 6,700.00 212.01 - 4,131.30 6,004,053.63 383,827.23 5.00 - 2,655.60 Top Kuparuk D 8,700.00 59.33 152.79 6,764.60 6,715.50 189.24 - 4,119.84 6,004,030.70 383,838.35 5.00 - 2,630.51 I 8,755.84 61.66 151.02 6,792.10 6,743.00 146.37 - 4,096.95 6,003,987.50 383,860.59 5.00 - 2,582.51 Top Kuparuk C 8,760.07 61.83 150.89 6,794.10 6,745.00 143.12 - 4,095.14 6,003,984.22 383,862.35 5.00 - 2,578.82 LCU - Top Nuigsut 8,800.00 63.52 149.68 6,812.43 6,763.33 112.31 - 4,077.56 6,003,953.15 383,879.47 5.00 - 2,543.63 8,900.00 67.77 146.79 6,853.67 6,804.57 34.91 - 4,029.59 6,003,875.04 383,926.27 5.00 - 2,452.94 8,936.73 69.34 145.78 6,867.10 6,818.00 6.47 - 4,010.61 6,003,846.32 383,944.82 5.00 - 2,418.81 Base Nuigsut 9,000.00 72.07 144.08 6,888.00 6,838.90 -42.39 - 3,976.29 6,003,796.96 383,978.39 5.00 - 2,359.14 9,100.00 76.41 141.49 6,915.17 6,866.07 - 118.99 - 3,918.09 6,003,719.50 384,035.44 5.00 - 2,262.93 9,200.00 80.77 139.00 6,934.95 6,885.85 - 194.31 - 3,855.40 6,003,643.25 384,096.98 5.00 - 2,165.05 9,227.64 81.98 138.32 6,939.10 6,890.00 - 214.83 - 3,837.35 6,003,622.47 384,114.72 5.00 - 2,137.80 Top Nechelik 9,300.00 85.15 136.56 6,947.21 6,898.11 - 267.78 - 3,788.73 6,003,568.80 384,162.54 5.00 - 2,066.25 11/19/2009 9 :00 :58AM Page 5 COMPASS 2003.16 Build 69 . , • ConocoPhillips HALL.IBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 15 Protect: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 15 Site: CD3 Fjord Pad North Referent'.e: True Welk Plan: CD3 -122 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -122 Design: CD3- 122wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Fasting DLS Vert Section (ft) ( ( °) (ft) ft (ft) (ft) (ft) (ft) 6,902.00 9,365.04 88.00 135.00 6,951.10 6,902.00 - 314.30 - 3,743.45 6,003,521.61 384,207.10 5.00 - 2,001.85 Start DLS 0.88 TFO 85.52 - 7" x 8 9,400.00 88.02 135.31 6,952.31 6,903.21 - 339.08 - 3,718.82 6,003,496.47 384,231.37 0.88 - 1,967.24 9,500.00 88.09 136.19 6,955.70 6,906.60 - 410.66 - 3,649.07 6,003,423.85 384,300.02 0.88 - 1,868.10 9,600.00 88.16 137.07 6,958.97 6,909.87 - 483.31 - 3,580.44 6,003,350.18 384,367.55 0.88 - 1,768.77 9,700.00 88.23 137.95 6,962.11 6,913.01 - 557.01 - 3,512.93 6,003,275.48 384,433.94 0.88 - 1,669.28 9,800.00 88.30 138.83 6,965.13 6,916.03 - 631.75 - 3,446.55 6,003,199.77 384,499.19 0.88 - 1,569.65 9,900.00 88.37 139.71 6,968.03 6,918.93 - 707.49 - 3,381.33 6,003,123.06 384,563.26 0.88 - 1,469.90 10,000.00 88.45 140.59 6,970.80 6,921.70 - 784.23 - 3,317.27 6,003,045.37 384,626.15 0.88 - 1,370.07 t 10,100.00 88.52 141.47 6,973.45 6,924.35 - 861.95 - 3,254.40 6,002,966.73 384,687.84 0.88 - 1,270.16 I 10,200.00 88.59 142.35 6,975.98 6,926.88 - 940.63 - 3,192.73 6,002,887.14 384,748.32 0.88 - 1,170.21 10,300.00 88.66 143.23 6,978.38 6,929.28 - 1,020.25 - 3,132.27 6,002,806.63 384,807.57 0.88 - 1,070.24 10,400.00 88.73 144.11 6,980.65 6,931.55 - 1,100.78 - 3,073.04 6,002,725.22 384,865.58 0.88 - 970.28 10,420.64 88.75 144.29 6,981.10 6,932.00 - 1,117.52 - 3,060.97 6,002,708.31 384,877.40 0.88 - 949.65 Start DLS 0.01 TFO - 0.16 10,500.00 88.76 144.29 6,982.83 6,933.73 - 1,181.94 - 3,014.66 6,002,643.20 384,922.73 0.01 - 870.33 1 10,600.00 88.76 144.29 6,984.99 6,935.89 - 1,263.12 - 2,956.31 6,002,561.16 384,979.85 0.01 - 770.38 10,700.00 88.77 144.29 6,987.15 6,938.05 - 1,344.30 - 2,897.95 6,002,479.12 385,036.98 0.01 - 670.42 10,800.00 88.78 144.29 6,989.29 6,940.19 - 1,425.48 - 2,839.60 6,002,397.08 385,094.10 0.01 - 570.47 10,900.00 88.78 144.29 6,991.42 6,942.32 - 1,506.66 - 2,781.24 6,002,315.04 385,151.23 0.01 - 470.52 I 11,000.00 88.79 144.29 6,993.53 6,944.43 - 1,587.84 - 2,722.89 6,002,233.00 385,208.35 0.01 - 370.57 11,100.00 88.80 144.29 6,995.64 6,946.54 - 1,669.02 - 2,664.53 6,002,150.96 385,265.48 0.01 - 270.62 11,200.00 88.80 144.29 6,997.73 6,948.63 - 1,750.20 - 2,606.18 6,002,068.92 385,322.61 0.01 - 170.66 11,300.00 88.81 144.29 6,999.81 6,950.71 - 1,831.38 - 2,547.82 6,001,986.88 385,379.73 0.01 -70.71 11,400.00 88.82 144.29 7,001.88 6,952.78 - 1,912.56 - 2,489.46 6,001.904.84 385,436.86 0.01 29.24 11,500.00 88.83 144.29 7,003.94 6,954.84 - 1,993.74 - 2,431.11 6,001,822.80 385,493.98 0.01 129.20 11,600.00 88.83 144.29 7,005.98 6,956.88 - 2,074.92 - 2,372.75 6,001,740.76 385,551.11 0.01 229.15 11,700.00 88.84 144.29 7,008.02 6,958.92 - 2,156.11 - 2,314.39 6,001,658.72 385,608.24 0.01 329.10 11,800.00 88.85 144.29 7,010.04 6,960.94 - 2,237.29 - 2,256.04 6,001,576.68 385,665.36 0.01 429.06 , 11,900.00 88.85 144.29 7,012.04 6,962.94 - 2,318.47 - 2,197.68 6,001,494.64 385,722.49 0.01 529.01 12,000.00 88.86 144.29 7,014.04 6,964.94 - 2,399.65 - 2,139.32 6,001,412.60 385,779.62 0.01 628.97 12,003.05 88.86 144.29 7,014.10 6,965.00 - 2,402.12 - 2,137.55 6,001,410.10 385,781.36 0.14 632.02 Base Nechelik 12,100.00 88.87 144.29 7,016.02 6,966.92 - 2,480.83 - 2,080.97 6,001,330.56 385,836.75 0.01 728.92 12,200.00 88.87 144.29 7,017.99 6,968.89 - 2,562.01 - 2,022.61 6,001,248.52 385,893.87 0.01 828.88 12,300.00 88.88 144.29 7,019.95 6,970.85 - 2,643.20 - 1,964.25 6,001,166.47 385,951.00 0.01 928.83 12,400.00 88.89 144.29 7,021.90 6,972.80 - 2,724.38 - 1,905.89 6,001,084.43 386,008.13 0.01 1,028.79 12,500.00 88.89 144.29 7,023.84 6,974.74 - 2,805.56 - 1,847.54 6,001,002.39 386,065.26 0.01 1,128.75 1 12,600.00 88.90 144.29 7,025.76 6,976.66 - 2,886.74 - 1,789.18 6,000,920.35 386,122.38 0.01 1,228.70 12,700.00 88.91 144.29 7,027.67 6,978.57 - 2,967.93 - 1,730.82 6,000,838.30 386,179.51 0.01 1,328.66 12,800.00 88.92 144.29 7,029.57 6,980.47 - 3,049.11 - 1,672.46 6,000,756.26 386,236.64 0.01 1,428.62 12,900.00 88.92 144.29 7,031.45 6,982.35 - 3,130.29 - 1,614.10 6,000,674.22 386,293.77 0.01 1,528.57 13,000.00 88.93 144.29 7,033.33 6,984.23 - 3,211.48 - 1,555.74 6,000,592.17 386,350.90 0.01 1,628.53 13,100.00 88.94 144.29 7,035.19 6,986.09 - 3,292.66 - 1,497.38 6,000,510.13 386,408.03 0.01 1,728.49 13,200.00 88.94 144.29 7,037.04 6,987.94 - 3,373.84 - 1,439.03 6,000,428.09 386,465.16 0.01 1,828.44 11/19/2009 9 :00 :58AM Page 6 COMPASS 2003.16 Build 69 O R I G I N A L • • ConocoPhilli s p HALLIBURTDN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) © 49.10ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon le Site: CD3 Fjord Pad North Reference: True Welt: Plan: CD3 - 122 Survey Calculation Method: Minimum Curvature Wetibore: Plan: CD3 -122 Design: CD3- 122wp03 - - - - -- -- - - ---- - -- - -- --- Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NJ-S +EJ-W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) 6,989.78 13,300.00 88.95 144.29 7,038.88 6,989.78 - 3,455.03 - 1,380.67 6,000,346.04 386,522.29 0.01 1,928.40 13,400.00 88.96 144.29 7,040.71 6,991.61 - 3,536.21 - 1,322.31 6,000,264.00 386,579.41 0.01 2,028.36 13,500.00 88.96 144.29 7,042.52 6,993.42 - 3,617.40 - 1,263.95 6,000,181.96 386,636.54 0.01 2,128.32 , 13,600.00 88.97 144.29 7,044.32 6,995.22 - 3,698.58 - 1,205.59 6,000,099.91 386,693.67 0.01 2,228.28 13,700.00 88.98 144.29 7,046.11 6,997.01 - 3,779.76 - 1,147.23 6,000,017.87 386,750.80 0.01 2,328.24 13,800.00 88.99 144.29 7,047.89 6,998.79 - 3,860.95 - 1,088.87 5,999,935.82 386,807.93 0.01 2,428.19 13,900.00 88.99 144.29 7,049.65 7,000.55 - 3,942.13 - 1,030.51 5,999,853.78 386,865.06 0.01 2,528.15 14,000.00 89.00 144.29 7,051.41 7,002.31 - 4,023.32 - 972.15 5,999,771.73 386,922.19 0.01 2,628.11 14,100.00 89.01 144.29 7,053.15 7,004.05 - 4,104.50 - 913.79 5,999,689.69 386,979.32 0.01 2,728.07 14,200.00 89.01 144.29 7,054.87 7,005.77 - 4,185.69 - 855.43 5,999,607.64 387,036.46 0.01 2,828.03 14,300.00 89.02 144.29 7,056.59 7,007.49 - 4,266.87 - 797.07 5,999,525.60 387,093.59 0.01 2,927.99 14,400.00 89.03 144.29 7,058.30 7,009.20 - 4,348.06 - 738.70 5,999,443.55 387,150.72 0.01 3,027.95 14,500.00 89.03 144.29 7,059.99 7,010.89 - 4,429.25 - 680.34 5,999,361.51 387,207.85 0.01 3,127.91 14,600.00 89.04 144.29 7,061.67 7,012.57 - 4,510.43 - 621.98 5,999,279.46 387,264.98 0.01 3,227.87 14,700.00 89.05 144.29 7,063.34 7,014.24 - 4,591.62 - 563.62 5,999,197.42 387,322.11 0.01 3,327.83 14,800.00 89.05 144.29 7,064.99 7,015.89 - 4,672.80 - 505.26 5,999,115.37 387,379.24 0.01 3,427.79 14,900.00 89.06 144.29 7,066.64 7,017.54 - 4,753.99 - 446.90 5,999,033.32 387,436.37 0.01 3,527.76 15,000.00 89.07 144.29 7,068.27 7,019.17 - 4,835.18 - 388.54 5,998,951.28 387,493.51 0.01 3,627.72 15,100.00 89.08 144.29 7,069.89 7,020.79 - 4,916.36 - 330.17 5,998,869.23 387,550.64 0.01 3,727.68 15,200.00 89.08 144.29 7,071.49 7,022.39 - 4,997.55 - 271.81 5,998,787.19 387,607.77 0.01 3,827.64 15,300.00 89.09 144.29 7,073.09 7,023.99 - 5,078.74 - 213.45 5,998,705.14 387,664.90 0.01 3,927.60 • 15,363.81 89.09 144.29 7,074.10 . 7,025.00 , - 5,130.54 - 176.21 5,998,652.79 387,701.35 0.01 3,991.38 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ") r) 2,810.61 2,500.00 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 9,365.04 6,951.10 7" x 8 -3/4" 7 8 -3/4 15,363.81 7,074.10 4 -1/2" x 6 -1/8" 4 -1/2 6 -1/8 11/19/2009 9 :00 :58AM Page 7 COMPASS 2003.16 Build 69 r ,...) , .' * x „.,.., . • • ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 122 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 1& Project: Western North Slope MD Reference: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19 Site: CD3 Fjord Pad North Reference: True Well Plan: CD3 - 122 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3 - 122 Design: CD3- 122wp03 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ( 8,760.07 6,794.10 LCU , 7,085.70 5,501.10 Albian 97 8,936.73 6,867.10 Base Nuiqsut 8,592.27 6,706.10 K -1 I 4,984.72 4,021.10 K -3 Basal 5,174.81 4,154.10 K -2 Basal I I 7,529.83 5,875.10 Albian 96 I 8,760.07 6,794.10 Top Nuiqsut 8,515.19 6,660.10 Base HRZ I 12,003.05 7,014.10 Base Nechelik 4,781.76 3,879.10 K -3 8,670.17 6,749.10 Top Kuparuk D I I I 5,024.74 4,049.10 K -2 3,346.74 2,875.10 C -20 8,755.84 6,792.10 Top Kuparuk C 9,227.64 6,939.10 Top Nechelik 8,327.61 6,535.10 Top HRZ Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 400.00 400.00 0.00 0.00 Start Build 1.50 600.09 600.00 3.70 -3.70 Start DLS 2.20 TFO 5.00 1,106.53 1,100.00 59.89 -53.84 Start DLS 2.75 TFO -48.75 2,386.40 2,203.20 276.67 - 622.31 Start 4481.09 hold at 2386.40 MD 6,867.49 5,338.37 921.37 - 3,758.43 Start DLS 5.00 TFO - 137.91 9,365.04 6,951.10 - 314.30 - 3,743.45 Start DLS 0.88 TFO 85.52 10,420.64 6,981.10 - 1,117.52 - 3,060.97 Start DLS 0.01 TFO -0.16 15,363.81 7,074.10 - 5,130.54 - 176.21 TD at 15363.81 11/19/2009 9:00:58AM P eh I r'^. COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3 -122 Plan: CD3 -122 CD3- 122wp03 • Sperry Drilling Services Clearance Summary Anticollision Report 18 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -122 - Plan: CD3 -122 - CD3- 122wp03 • Well Coordinates: 6,003,526.86 N, 1,527,986.44 E (70° 25' 08.18" N, 150° 54' 57.37" W) Datum Height: Plan: CD3 -122 (36.3 +12.8) @ 49.10ft (Doyon 19) Scan Range: 0.00 to 15,363.81 ft. Measured Depth. Scan Radius is 1,732.75 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:48, November 18 2009 3 CD3- 122wp03 Ellipsoid Color 36.30 To 15363.81 CD3 36 250 1750 — 2000 5000 6000 14000 1600C 250 _ 500 2000 2500 6000 7000 16000 1800C .:',D3 CD3 120wp02 500 750 2500 3000 7000 8000 18000 2000C vr / 360 750 1000 3000 3500 8000 9000 20000 25000 �`� 1000 1250 3500 4000 9000 10000 ', ► 46PS �,, . 1 1 �it . 4 V ►•1 �► 4 ) - . C D3 - 1250 1500 4000 4500 10000 12000 4��•!�':�; � I��r. 1500 1750 4500 5000 12000 14000 ilri � 6 4 i1• CD3- 119wp02 4 4 11 /111 / � r,��yjii'li�i; '/f ` .,�p�' r�l CD3 -111L� ". � • 1� � r .f �\ � \111/ ►I, III Ir iy l /�i � i I ,. � r �� ∎- q�r ► P . r �. a� ,� 1I C D3 - 11' ,/ S � A 6 rfit !l iVit ; * ��' /� .� CD3- 121wp0 "s 60 / 300 � �� /� jt y �� ♦ 1�1, ,i 6 0 �\ if lt I ¢ l by � . 0 / 360 ��� , r Vii " ml b � � d i $ 1 / 1 �► � V� �� �'� ` 4 ��h �o o ' 3 �� -.....D3-11C - 30 / 330 Al I s_ .. .. 30 �; NYC _ � � : " " � f f / \\ 1111,, , ,,t411/2a_, 1 1`I�'► �, �j��Rlit : =:�__ . 4 -�/ r _' °_ . e0$4* O,i, D3- D3 CD3 -123w 02 �ee****1; ;: � fpir= � - 'g. 1 e 1 /�/��6?' ��.. , -.. � / 1 / 60 / 300 `` y` ilic l / �f -.: Q � .. ► ` 0 1,1 ,Ill�lhri �6, § 1 -90 / 270 [ um illeIfllfiki , •, w iss 11111II� .n 11 1 10 1 , 1 , 1 1 1 1 9 g 1 4 1 � 1 1 1 , 1' 1 1 1 i f i I iu���, y R _ _`. ,� �`v�► / / � � /il 'gi • .fl . 0,��111111 1� � 1 ��ti1� �� �� x ,, `' 9� 1ta r .o �' ice" �p • • •�� 4.� ♦d l���.� 4 � y t t f 2m// V � . P VA� LY...i. j � j . e ,. 11 ■. r 'I i 90 / 270 y i.• e a.. , a, 90 ► •••...e. // I • �V• i 1 A v ��11��∎ n raNg ya A 1 � ��1� { ���r �� � �� z . R \ nut a = .i. � �! n ! �� o � � : . �I\ Vii: \ \ ��I f u.�a�� \��m�s� / % ►' � lows.-100 , 5 , 400.. � . p . I I� I��\ CD3.123w 0 A ° , i � 000.''"AV i \��• .0fifhl:,7,1eXtrOlvdRi-4.t/i1;144111,*41,070:16. " ► • 1 , H • ►� t b > �aTra ' ����5 n�� Q . �+aP� � 1� \ � • -4i -120/240 120 � \� : :�'e � � f, ��� /�% ! ®V �.4�1' is' m \• A► tea. / . � .. D3- 316AP61 -120 / 24 0 , rail/WINONA � 120 . s i,S► Vii► iw, ,Z; \ `a '.1"----.1- ,. /` V p► v, ,,r �y \,. , ` �. . � C D3 -316 �r ®�� �` �`` �• I1 N�N ` e = F� � a �� \ � `a ,�L�`� �,��r k C D3- 124wp02 bil ri �� ∎11/ i � �� , .11 1a.. . r /- ��� CD3 31 �: . l'. � ` \ ... 3 150 /2 �4 1 11� 150 150 / 21 / '/1. al `�f \�4 \`\� %' , ° t- � � 5 0 . CD3 125wp02 � �� • • . i p e . i. �\l�- l Alm -180 / 180 CD3 -118 I r� k �'0.V ' CD3- 126wp02 CD3- 124wp0 CD3 -11f -180 / 180 CD3 -117 2D3 -115 CD3 -114 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft /in] Easting (3000 ft/in) I I I I I I I 1 1 1 I 1 1 1 1 I 1 1 1 I 1 1 1 1 I 1 1 1 I 1 ' l i l t ' ' l i l t ' ' , ConocoPhillips(Alaska) Inc. -WNS CD3 126wp02 Western North Slope CD3 125wp0 CD3 Fiord Pad - CD3 -110 - CD3 -111. 1 CD3 -11 CD3 -112 - CD3 -113 CD3 -11 - _ - z - o _ CD3 -11 CD3 -11 _ - CD3 12 -11 ° - D3 -31 GAP CD3 -316 CD3 -317K _�' C D3 -120w 3- 119wp02 _ CD3-121wp02 CD3- 122wp03 =* CD3- 123wp02 Easting (3000 ft/in) ConocoPhillips(Alaska) Inc. -WNS , HALLI BURTON Western North Slope Anticollision Report for Plan: CD3 -122 - CD3- 122wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -122 - Plan: CD3 -122 - CD3- 122wp03 Scan Range: 0.00 to 15,363.81 ft. Measured Depth. Scan Radius is 1,732.75 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad • CD3 -110 - CD3 -110 - CD3 -110 99.38 240.06 99.38 238.22 100.00 130.721 Centre Distance Pass - Major Risk CD3 -110 - CD3 -110 - CD3 -110 324.37 241.58 324.37 235.46 325.00 39.443 Clearance Factor Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 569.68 214.70 569.68 204.16 575.00 20.374 Centre Distance Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 593.96 214.84 593.96 203.98 600.00 19.774 Clearance Factor Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 569.68 214.70 569.68 204.16 575.00 20.374 Centre Distance Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 593.96 214.84 593.96 203.98 600.00 19.774 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 1,431.13 163.76 1,431.13 140.36 1,475.00 6.997 Centre Distance Pass - Major Risk f" CD3 -112 - CD3 -112 - CD3 -112 1,477.41 164.18 1,477.41 139.79 1,525.00 6.734 Clearance Factor Pass - Major Risk o CD3 -113 - CD3 -113 - CD3 -113 149.20 179.44 149.20 176.59 150.00 62.940 Centre Distance Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 8,061.19 196.89 8,061.19 36.57 8,125.00 1.228 Clearance Factor Pass - Major Risk ----° CD3 -114 - CD3 -114 - CD3 -114 399.05 159.62 399.05 151.94 400.00 20.798 Centre Distance Pass - Major Risk G") CD3 - 114 - CD3 - 114 - CD3 - 114 812.20 165.14 812.20 149.59 825.00 10.621 Clearance Factor Pass - Major Risk -., CD3 -115 - CD3- 115 - CD3 -115 1,318.83 54.64 1,318.83 32.49 1,350.00 2.466 Centre Distance Pass - Major Risk CD3 - 115 - CD3- 115 - CD3 -115 1,367.11 54.94 1,367.11 32.22 1,400.00 2.418 Clearance Factor Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 837.05 75.83 837.05 59.79 850.00 4.728 Centre Distance Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 860.63 76.00 860.63 59.65 875.00 4.646 Clearance Factor Pass - Major Risk CD3 -118 - CD3 -118 - CD3 -118 1,013.13 37.43 1,013.13 21.02 1,025.00 2.281 Centre Distance Pass - Major Risk • CD3 -118 - CD3 -118 - CD3 -118 1,037.20 37.62 1,037.20 20.79 1,050.00 2.236 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 595.78 117.18 595.78 106.44 600.00 10.919 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 620.05 117.40 620.05 106.33 625.00 10.610 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 595.78 117.18 595.78 106.44 600.00 10.919 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 620.05 117.40 620.05 106.33 625.00 10.610 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 595.78 117.18 595.78 106.44 600.00 10.919 Centre Distance Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 620.05 117.40 620.05 106.33 625.00 10.610 Clearance Factor Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 225.00 60.04 225.00 55.79 225.00 14.115 Centre Distance Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 474.33 61.47 474.33 52.42 475.00 6.790 Clearance Factor Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 424.85 39.90 424.85 31.80 425.00 4.925 Centre Distance Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 549.22 41.06 549.22 30.59 550.00 3.921 Clearance Factor Pass - Major Risk 18 November, 2009 - 13:42 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -122 - CD3- 122wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -122 - Plan: CD3 -122 - CD3- 122wp03 Scan Range: 0.00 to 15,363.81 ft. Measured Depth. Scan Radius is 1,732.75 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Plot CO3-121 - Plan: CD3 -121 - CD3 -121 wp02 449.87 19.84 449.87 11.27 450.00 2.313 Centre Distance Pass - Major Risk Platt CD3 -121 - Plan: CD3 -121 - CD3-121114:02 699.28 22.26 699.28 8.92 700.00 1.668 Clearame Factor Pass - Major Risk Plant CD3 -123 - Platt CD3 -123 - CD3- 123wp02 350.00 20.01 350.00 13.35 350.00 3.004 Centre C4sbraice Pass - Major Risk III Platt CD3 -123 - Plan: CD3 -123 - CD3- 123wp02 801.41 24.20 801.41 8.91 800.00 1.583 Clewance F Pass - Major Risk Plan: CD3 -124 - Plan: CD2 -124 - CD3- 124wp03 400.00 40.03 400.00 32.35 400.00 5.216 Centre Distance Pass - Major Risk Plan: CD3 -124 - Plan: CD2 -124 - CD3- 124wp03 525.64 41.05 525.64 30.99 525.00 4.081 Clearance Factor Pass - Major Risk Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 600.06 56.54 600.06 45.10 600.00 4.940 Centre Distance Pass - Major Risk Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 624.75 56.70 624.75 44.77 625.00 4.754 Clearance Factor Pass - Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 625.99 79.23 625.99 67.30 625.00 6.642 Centre Distance Pass - Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 675.43 79.58 675.43 66.69 675.00 6.175 Clearance Factor Pass - Major Risk Survey tool program From To Survey /Plan Survey Tool (ft) (ft) e" - 36.30 1,000.00 CD3- 122wp03 GYD -CT -CMS 6 1,000.00 15,363.81 CD3- 122wp03 MWD +IFR- AK- CAZ -SC • Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 18 November, 2009 - 13:42 Page 3 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLI BURTON Western North Slope Anticollision Report for Plan: CD3 -122 - CD3- 122wp03 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3 -122 (36.3 +12.8) © 49.10ft (Doyon 19). Northing and Easting are relative to Plan: CD3 -122 - Slot 22. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.86 °. Ladder Pe 1 LEGEND • ' I r 1 1 ( �i r k I -- CD3- 110,CO3- 110,CO3.110V12 C 1 PI ►, r! I y . V 5 1500 ; � ' A ,�; �• ' -9- CD3- 111,cD3- 111,CD3 -111 V7 p 1 , y i � T f CD3- 111,CD3- 111L1,CD3 -111 L1 V1 40 1 , a 1 1 CD3.112,CD3- 112,CD3 -112 V'3 r .I I ' 2 j �;`% ij 1 CO3.114,CO3.114,CO3- 114V14 -�' ( (O ;3 I R i+ ►� r / I 1 - - CD3-115,CD3-115,CD3.115V0 1000 ' • h ii ' I - , � , r - '� pr . B CD3- 117, CD3- 117,CD3.117VO 1 1 " $ CD3- 118,CD3.118,CD3 -118VO 11 / �`l ; 11 - - - -�' I 1 I ---- - CD3- 316.0O3- 316,CD3 -316 VU 4 . . + , 1 - CD3 -316, CD3- 316A,cD3.316AV>) 1 VD "' 0 I + i P 1 ,,: fr r ly • : . _�� I PI CD3- 1 1 V1] X00 •. { � � '�`r {, r 1 I I - - Plan: CD3- 120,PIan:CD3.120,CD3.120wp02 V1] �' �` , e ' 1 1 I 1 -e- Plan: CD3 .121,Plan:CD3- 121,CD3- 121wp02VO . ,. /,,'J 1 1 1 I I - Plan: CD3. 123,PIan:cD3.123,CD3.123wp02V17 i . 3 �_� � , ' ,1, . r I I I 1 -Q- Plan: CD3 .124,Plan:CD2- 124,CO3- 124wp03 VO :- 1 1 1 1 - Plan: CD3- 125,PIan:CD3- 125,CD3- 125 wp02 VD - { 1 1 1 1 I 0 1 ' 1 1 1 - Plan: CO3- 126,PIan:CD3- 126,CD3- 126wp02 V13 0 1500 3000 4500 6000 7500 -B- CD3-122wp03 Measured Depth (1 500 ftlin ) 18 November, 2009 - 13:42 Page 4 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -122 - CD3-122wp03 p p Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor low _ lartfriri 101111 ..11111 --- LEGEND $'5 tlil � CO3.110,CO3 -110, CD3-110 V12 ii j jq CO3.111,CO3.111,CO3 -111 V7 7a1 j7j1 7 - CD3- 111,CD3- 111L1,CO3 -111 L1 V1 �_ _ + S i / l- w � CO3- 112,CO3.11,CD3 -112 V3 1 ,/ CO3 -113,0 03.1133, CD3- 113V1B 6. 625 - ': ' �+ t • 1 �.��1i -- CD3 114,CD3 114,003-114 V14 7" .,i `o _ t s 1 -- CO3.115,CD3.115,CO3 -115 VD {{"� c j -a- CO3- 117,CO3- 117,CD3 -117 rr^�.< a �� � • A i 1m imii �,ie $ CD3 -118, C 03-118, CD3.118 _114/ mill VD /�'`'� C133-316 , C 03.316, CO3 -316 VD L,J > _ /1 ri - CD3 -316, CD3 -316A, CD3- 316AV0 Q 3;5-- w - CD3 .316,CD3.316APB1,CD3.316APB1VD ul _ Y + - Plan: CD3- 119,PIan:CD3- 119,003- 119wp02VO _ r 4- P : C CD3 D3- . 1 120 21, , PIan PIan: :CD3- CD3.120 12 121wp 0wp 02 D2 V 1] r - 250 _ r - t i -- Plan: CD3 .123,PIan:CO3.123,C133- 123wpD2 VO ti, e -0.- Plan: CD3- 124,PIan:CD2- 124,CD3- 124wp03 VD 125 Plan: CO3- 125,PIan:CD3- 125,003- 125wp02 VO -X- Plan: CD3- 126,PIan:CD3- 126,003- 126wp02 VD - -a CD3- 122wp03 000 I I I I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 I 0 750 IS:0 2l) 3X0 3'a0 M0 350 610 us) 730) ) 9330 Measured Depth (1500 MI n) 18 November, 2009 - 13:42 Page 5 of 5 COMPASS ✓ Project: Western North Slope ConocoPhillips Site: CD3 Fiord Pad C D 3 -12 2w p 0 3 Well: Plan: CD3 -122 Wellbore: Plan: CD3 -122 HALLIBURTON CD3- 122wp03 Quarter Mile View Sperry Drilling - - N 031 GV ^ CP 9 GP4/ ala V‘Y11 NV 2000 1 I � P 4" c., 0 Go y ���.� _— m 1 0 W ? 2000 ' UIi!i& k& l � z 411 16, X 4000 - o • (f) rig 4. ^ titi -6000 _' - 8000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 West( -) /East( +) (2000 ft/in) Operdor: Ca,000pnRp3(A10k011c. -KNS GrdCorrection. -086 ° JobNo: MN /A WI Western North SM. Mrgwlic Decrndlon• 2135 ° AR No: 4N /A VNR C133- 122wp03 Dip 80.78 " API No: MN /A Rig MN /A Dogpgper 100 I1 System 03 DIRNNMCt: MO,5000evd Sunoco Weak. Original VS Plane: 143.00 . Po..nt wet Plcm CD3 -122 X 1527086.44 1t View VS Plane: 143.00 ° RKBII441t: 40.10 R 3: 600352686 1t Unit System: API Based / WS 5ecllon (VS) RNNence: Slot Comments: POOL: Inn view S o 0 0 0 ° 8 0 0 o S o 0 d P O Q O P O rO N h h 2 N N CV CO ■ CD3- 122wp03 Plan: 9365' to 15363.81' MD _ _ _ _ _ _ _ ^ 6014000 CD3 -114: 10669' to 18042' MD 6013000 CD3 -113: 9364' to 17338' MD 65 __ ____ -___ _ 6012000 CD3 -112: 8495' to 16021' MD - 6011000 ,s.; - - - -- - - - --- - 6010000 ,. _ -_ _ _ - -_- - _ -___ — — • 6009000 _-- -_. -__ ___ _. _ -._ _ -. _ - -_.. - 6008000 • _____ __ ____ ____ __ -____ ___..- _____- ___ —_: - - -_- 6007000 z o -- - -- 6006000 6005000 - II P Sec 6004000 Section View �- CD3- 122wp03 Plan —CD3 -114 —•— - CD3 -113 -CD3 -112 6003000 - -- - 6002000 Cr ) 1 • 6001000 �..�,.eM. 1 _6000000 5999000 >6 6 1 I -___ _— - _ - -___. _� -__. 5998000 f - 5997000 5996000 L N East (3-) / West 1 -) 0 ll 8 t • 2 1 E Si 1 a \ ~ al OO OOOOOOO ill — 7100 p p p p p - 1 p p 8 8 8 8 8 8 8 8 -O i Q _ _ P U N` P , ) P Vert icd Sect ion Bong "View VS Plane" Combo Preuew Page 1 of 1 (CD3- 122v4)03 Todbox)ds) 11/18/2009 3:40 PM Closest in POOL Closest Approach: Reference Well: CD3- 122wp03 Plan Offset Well: CD3 -113 Coords. - Coords. - ASP ASP 3 -D ctr -ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( + /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (143) Comments Depth Angle Azi. TVD E( +) /W(- (143) - .Comments POOL Min POOL Min Distance (2158.82 Distance (2158.82 ft) in POOL (9365 - ft) in POOL (9365 - 15363 81 MD) to 15363.81 MD) to CD3 -113 (9364 - CD3- 122wp03 Plan 2158.8 9365.04 88 135 6902.076 6003269 1524239 - 2001.88 17338 MD) 9339 83.77 328.33 6857.67 6005057 1523029 -4229 1 (9364 - 17338 MD) Closest Approach: Reference Well: CD3- 122wp03 Plan Offset Well: CD3 -112 Coords. - Coords. - ASP ASP 3-D ctr -ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (143) Comments Depth Angle Azi. TVD E( +) /W(- (143) Comments 7 .3 POOL Min POOL Min Distance (3135.46 Distance (3135.46 ft) in POOL (9365 - ft) in POOL (9365 - 15363.81 MD) to 15363.81 MD) to °"""'= CD3 -112 (8495 - CD3- 122wp03 Plan R - n 3 9365.04 88 135 6902 076 6003269 1524239 - 2001.88 16021 MD) 8482.57 83.16 321.36 6864.41 6006362 1524753 - 4196 06 ( 8495 - 16021 MD) .7*.: Closest Approach: Reference Well: CD3- 122wp03 Plan Offset Well: CD3 -114 g..,' - Coords. - Coords. - f ASP ASP 3-D ctr -ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (143) Comments Depth Angle Azi. TVD E( +) /W(- (143) Comments POOL Min POOL Min Distance (3310 4 ft) Distance (3310.4 ft) in POOL (9365 - in POOL (9365 - 15363.81 MD) to 15363.81 MD) to CD3 -114 (10669 - CD3- 122wp03 Plan 3310.4 9365.04 88 135 6902 076 6003269 1524239 -2001.88_18042 MD) 10644 06 83.64 325.26 6878.99 6004221 1521069 - 4703.52 (10669 - 18042 MD; PoolSummaryl 11/18/2009 4:04 PM • • CD3-122 Surface Location: (PM Coordinate Convei ter From: To: Region: z i Region: lalaska Datum: NAD83 1NAD27 alaska Datum: r - Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees C UTM Zone: r South C UTM Zone: T, F South 4 State Plane Zone: Units: ,r71 4.`a" State Plane Zone: T, Units: us -ft 4" Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11527986.44 Township: r ----- 012 Range: 1 1005 Y: 16003526.86 Meridian: lu j Section:15 FNL j 13998.2163 11088.4197 Transform Quit Help 1 CD3-122wp03 Intermediate Casin. Point: CPAI Coordinate Converter X From: To: Datum: 1NAD83 j Region: alaska Datum: 1 INAD27 v Region: lalaske Latitude/Longitude !Decimal Degrees C Latitude/Longitude !Decimal Degrees UTM Zone: f South C UTM zone: Trine 1 — South (** State Plane Zone: Units: L T;TF, r State Plane Zone: True H Units: us -ft f:■;' Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11524239.00 Township: Foi :fs,j± Range: Y: 6003269.00 Meridian: fir Section:15 P832.79.64 Transform Quit I Help ORIGINAL • 0 CD3-122wp03 TD/Toe: _....„ I!1 CPAI Coordinate Converter 1 From: To: 1 Datum: 1NAD 83 . Region: alaska , ,. Datum: ]NAD27 .,.. Region: alaska , — , C Latitude/Longitude !Decimal Degrees , C Latitude/Longitude Decimal Degrees ■ I C UTM Zone: 1 1 South r UTM Zone: J7 — f South 4 State Plane Zone: r71 Units: us-ft . C State Plane Zone: T Units: i r j 7fT,. is Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11527733 00 Township: ra i012 I..p Range: r 1005 Y: 15998400.00 Meridian: u , Section:18 FL' 1'3848 4847 IFE2 11286.2867 Transform I , Quit Help I riD ,o, IGINAL GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:50, November 18 2009 CD3- 122wp03 Ellipsoid Color 36.30 To 500.00 36 " "" "" 250 1750 2000 5000 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 30 / 330 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 50 -30 / 330 30 D3 -11 10 � 'D3 -111 L � D3 -121 D'i. ;, Y , __am - 60 / 300 60 1. i e - 6 t � - - �� 3- 121wp11 3D3- 120wp0 "e alill I. 3- 123wp0' � � ° 90 / 270 p3'1CCiv` L'7i 90 �� ; _J ' D :7tiEZE (41) ms �i m D3- 123wp0 - D3 -124w. \ \ \ \ �� "`TA' 90 ■ -90 / 270 ���� -11.1. VJ 3D3- 124wp0Z �� -120 /240 120 1 -120 /240 120 III 200 - 150/210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:51, November 18 2009 B CD3- 122wp03 Ellipsoid Color 500.00 To 1000.00 36 250 1750 2000 5000 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 4000 9000 " "" "" " 10000 P 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 200 -60 60 D3.121wp0 / ' 3D3 -11t 30 / 330 30 .•0' . r ..._...., . - D 3 119w _ 1 � °��" : CD3- 120wp0 •.av : 'a h+ 60/ • • •• re "..4*:„141‘, . • • X 60 -90 / 270 sa 6 ,, /, 90 "� \ , �� \i � � ; � / ' f a ' - I Ii A D3 -123wp \ \���ii y_ rat �i. O \ \� a r ...r,' 11 � em u - . `1 r < < \� !� j� i` :�I ' q1�� D3- 316APB1 -90 / 270 ri . T. / (I —� ���' ■ 4 90 , 741' , / Asti• . r rnia4 .i�l 11Oi �•�g r D3 -11 CD3 -316F. / \h \ \ \ • CD3- 124wp03 w �, rtAV�,� �/ �% r D3 -3 0 :� \ CD3 -125w 0 ' 120 � �� ' ..+oi -= Cr 120 /240 p `l + , CD3 -126w -120 / 240'lAll • s • � 200 120 � OI, CD3- 124wp09 N fit1 CD3 - 118 ill ��L -150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:51, November 18 2009 CD3- 122wp03 Ellipsoid Color 1000.00 To 1500.00 36 250 1750 2000 5000 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 18000 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - 30/ 330 30 1500 1750 4500 5000 12000 14000 A. CD3- 119wp02 i CD3 -111L' 200 =', ' • I OwPO it irsir ii:, CD3 -11' 3D3 -121w 02 -60 / 300 �� 5�`i1. , ' _ . 60 D3 -121w N tiE s ` t 0 / 360 p'� � %: �'� -:' c -ma -: • ..�'t N \.�` -30 / 330 �Alli ��� irf I( � ''' y 4 q p 1\ '% -60 / 300 ��1ig!111� 60 ., 90 / 270 c .1 t \11 r� 90 i litiiiimagpi.- �. �i �. �a ' � ..ii 90/270 �ij.�90 31 21.1h. ---- k Ill I l e i m • e l I 1 Mahn ,Otig,44.41 ,....„,,,,,,,,,,,,..,:„„ j���� t7:1` 7A 91�► i�j���� CD3- 123wp0i - -- — 41 120 / 240 r`� =� ���► 4 ,5 a' &14. ir A tat 1� 120 / ' "0 �/�/� 10,, " :i l k C�!� D3 - 11 .r . ' aciv, ∎ 0 :, Mr N Iir,► 120 / 24� - -,r )))/// ' / I� /I ►� 120 • .1, 1 ., �� - �` • 04 ,4 1 � r CD3 316AP61 /,a�/ � 1 1 I iii%, �� goo- im- . 4IPP .0-0 ;D3 -316A � 4 01 '517 3D3- 11f ��� A.Op44p- D3 -125w 3 -31E 150 / 210 Af C i _ . ��� 150 ' 4��,4 -180 / 180 300 CD3- 126wp02 CD3 -118 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference 13:52, November 18 2009 CD3- 122wp03 Ellipsoid Color 1500.00 To 2000.00 36 250 1750 2000 5000 6000 14000 1600 250 500 2000 2500 6000 7000 16000 1800 CD3 120wp0 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 "" 4000 9000 10000 ��` CD3 - 112 1250 1500 4000 4500 10000 12000 30 / 330 CD3 121wp02 d 30 1500 1750 4500 5000 12000 14000 4 t I4 1 200 6 0 / 300 ` }, 7J' 50 30 / 330 30 C' c- 123wp0 ' -60 / 300 60 -90 / 270 1>A,,, � \ �� 90 , r / �D. -11: -90 / 270 90 e , r- 1111PI 120 / 240 <'f O. I i A 120 y 200 ���I UII � ►���111���, 120 / 240 120 • / � , .�1� / : -11- -150/210 150 • Q\r -150 / 210 l�V 150 50 J / % 180 / 180 300 10D3- 124wp03 D3 -11f - 180 / 180 OD3 -117 D3 -11 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:53, November 18 2009 CD3- 122wp03 Ellipsoid Color 2000.00 To 2500.00 36 250 1750 2000 5000 6000 14000 16001 D3 - 121wp02 250 500 2000 2500 6000 7000 16000 18001 500 750 2500 3000 7000 8000 18000 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 25006 / ... -49.� T 300 30 1000 1250 3500 4000 9000 10000 li• ► • i,' 1250 1500 4000 4500 10000 12000 - / 330 :, ii►i�� , -� . ;, ' D3 -110 } 4 411►� 1500 1750 4500 5000 12000 14000 � yyr, P44:� �\ \1 N_ - 2200 ( zwvokgtp. 41 ;:.,,, V� �t ,s -60 / 300 \"% 60 0 / 360 50 -30 / 330 30 101 D3- 123wp0' ...Au.* A -60 / 300 60 ._ //1 %ii1111► Ali -90 / 270 ktriergm � so it -90 / 270 90 -120 / 240 -120 / 240 120 �� 200 In ;; fila ;hat Q `, ..,.,r• . Al p `►; .;. .� _ ��\ ��� ��\ \ 150 / 210 150 I\� li�� ��.;, ..,,` ���� 50 150 / 210 ii ^' , \ \\ � u �p Um.► i , u���. -180 / 180 - l.1l,'i �� ii°° n'' Ali.!! - = -180 / 180 .:.:D3 -114 OD3 -114 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:55, November 18 2009 r CD3- 122wp03 Ellipsoid Color 2500.00 To 3500.00 36 250 1750 2000 5000 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 50 -30 / 330 30 A1101 D3 123w 02 �#111/140141 'I ♦'•• -- p l/I 60 / 300 60 -90 / 270 � 90 / /Lk . v.4.4t.44,:ttttatt,.... ... -90 / 270 90 II 1 -120 / 240 120 -120 /240 120 • 200 -150 / 210 150 150 /210 150 5 ;:, �� 1 -180 / 180 _i,1 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:56, November 18 2009 CD3- 122wp03 Ellipsoid Color 3500.00 To 7500.00 36 250 1750 2000 5000 - -- -- 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 30 / 330 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 200 • -60 / 300 60 0 / 360 50 -30 / 330 30 10' c..) /2:.3 -60 / 300 60 0 / 270 90 /II `�" -90 / 270 90 -120 / 240 120 IllIF 1 -120 / 240 120 • 200 -150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [O] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:57, November 18 2009 F CD3- 122wp03 Ellipsoid Color 7500.00 To 8500.00 36 250 1750 2000 5000 6000 14000 16000 250 500 2000 2500 6000 7000 16000 1800C :,'D3 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C ift 11 1000 1250 3500 4000 9000 10000 30 / 330 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 4111116/ kill � yite# � i .o ' / -60 / 300 ` �����a.� / 60 , 0 / 360 \``�"�� 30 / 330 ` 30 Nmiediverio., I � ` I -60 / 300 60 Aigh ' . f N‘ M t f t ` �� 1r�/ ' � ,�ILINE 1 A ll A w ll l -90 / 270 \ � 1 .. '% r 90 .! V � 1 1 1�i0 � � -90 / 270 90 tr A lirt \�\ -120 / 240 �� 120 -120 / 240 1 20 • 200 IF -150 /210 150 150 /210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:58, November 18 2009 i CD3- 122wpO3 Ellipsoid Color 8500.00 To 15363.81 36 250 1750 2000 5000 6000 14000 16000 250 500 2000 2500 6000 7000 16000 18000 500 750 2500 3000 7000 8000 18000 20000 0 / 360 750 1000 3000 3500 8000 9000 20000 25000 300 1000 1250 3500 "" 4000 9000 10000 30/ 330 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 200 -60 / 300 60 0 / 360 50 -30 / 330 30 4 1 101 -60 / 300 60 -90 / 270 90 Ilk MP -90 / 270 90 -120 / 240 120 -120 / 240 120 • 200 IF 150/210 150 150 /210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [25 ft/in] • • ConocoPhillips Alaska, Inc. ,�,, Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conocothillips Telephone 907 - 276 -1215 RECEIVED November 20 2009 ,..; v 202009 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 : Alaska i it c'St Gas Cons.Conmnissr. Anchorage, Alaska 99501 Anchorage Re: Application for Permit to Drill CD3 -122 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 pad. The intended spud date for this well is January 9 2009. It is intended that Doyon Rig 19 be used to drill the well. CD3 -122 will penetrate the reservoir horizontally. After setting the 7" intermediate casing, the horizontal • section will be drilled and the well completed as a Nechelik producer using Baker's multiple stage "Frac Point" system. A sundry 10 -403 permit will be submitted regarding the equipment and procedures used to complete the well. Once completed, the well will be flowed back to mitigate reservoir damage and then • hooked up to begin production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 6 winter season of drilling on the CD3 pad, and to date 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 Ryan Robertson at 265 -6318 or Chip Alvord at 265 -6120. Sincerely, 7 Ryan Robertson Attachments: cc: CD3 -122 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Nina Anderson ATO 1706 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference 13:58, November 18 2009 CD3- 122wp03 Ellipsoid Color 8500.00 To 15363.81 36 250 1750 2000 5000 6000 14000 1600 250 500 2000 2500 6000 7000 16000 1800 500 750 2500 3000 7000 8000 18000 2000 0 / 360 750 1000 3000 3500 8000 9000 20000 2500 300 1000 1250 3500 4000 9000 10000 30 / 330 30 1250 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 200 • -60 / 300 / 60 0 / 360 50 -30 / 330 30 _10 -60 / 300 60 -90 / 270 90 C . Ilk , -90 / 270 9 0 ......1 rri -120 / 240 120 -120 / 240 120 200 - 150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] Page 1 of 1 • Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan .G.Robertson @conocophillips.com] Sent: Wednesday, December 09, 2009 9:39 AM To: Schwartz, Guy L (DOA) Subject: CD3 -122 Info Attachments: CD3 -122 Casing Program Update - 12.08.09.xls Guy, Here is the corrected information for the tubing and casing for the CD3 -122 Permit to Drill. I've highlighted the depths and lengths that I changed. Thanks, Ryan Drilling Engineer i CConocePhi(iips Alaska ; Direct' r907) 265 ;33'.8 I Mobile: %90 7) 960-5107 12/9/2009 • ;D3 -122 18. Casing Program: Specifications Top • Setting Depth •Bottom Hob Casing Weight Grade CouPlt g Length , MD TVD MD TVD 3.5" 9.3 L-80 EJJE 6q6 32 32 Mit Tubing 6.125" 3.5" 9.3 L-80 IBT 6110 WOO and 15340 7074 Liner with Baker Frac Point system • TRANSMITTAL LETTER CHECKLIST WELL NAME Colville River Unit CD3 -122 PTD# 2091530 X Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Colville River POOL: Colville River, Fiord Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ., ifi z , rt >. - Field & Pool COLVILLE RIVER, FIORD OIL - 120120 Well Name: COLVILLE RIV FIORD CD3-122 -__ Program DEV Well bore seg ❑ PTD#: 2091530 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea 890 Unit 50360 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate No Correction to 10 -407: only affected lease is ADL 372105. 3 Unique well name and number Yes 4 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120, governed by CO 569. 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included _ Yes external property line where ownership or landownership changes. 9 Operator only affected party Yes 110 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 11/30/2009 114 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA • 16 Pre - produced injector: duration of pre production Less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 119 Surface casing protects all known USDWs NA No Aquifers.. Conclusion 3. AIO 30 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes Qannik to be cemented in 2nd stage. OH slotted liner over the Nechelik zone. 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes _ Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. CD3 -118 is 18' away at 1037' and . 27 If diverter required, does it meet regulations NA Diverter wiaver requested . No Shallow gas in CRU. 20 AAC 25.035(h)(2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max Formation pressure= 3201 psi ( 8.7 ppg) Will drill with 9-9.5 ppg mud. GLS 12/8/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2494 psi Will test BOPs to 3500 psi. 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S expected. Rig has alarms and sensors installed. 34 Mechanical condition of wells within AOR verified (For service well only) _ NA 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S andgas detectors will be used during drilling. Mitigation measures in Hazards Geology 36 Data presented on potential overpressure zones Yes Summary. 1 Appr Date 37 Seismic analysis of shallow gas zones NA Expected reservoir pressure is 8.7 ppg EMW; will be drilled with 8.7 - 9.8 ppg mud. SFD 11/30/2009 138 Seabed condition survey (if off - shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] _ NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date /z -i"7 S 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 g y organize this category of information. 1 • Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 03 15:52:37 2010 Reel Header Service name LISTPE Date 10/02/03 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 10/02/03 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD /MAD LOGS WELL NAME: CD3 -122 API NUMBER: 501032060900 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 03- FEB -10 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW- 0006991483 -MW- 0006991483 LOGGING ENGINEER: E. QUAM J. BOBBITT OPERATOR WITNESS: D. BURLEY F. HERBERT SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 3998 FSL: FEL: 1088 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 48.70 GROUND LEVEL: 12.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2685.0 2ND STRING 6.125 7.000 9130.0 3RD STRING PRODUCTION STRING Dc,9 — r5 3 /93 �3 • • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ONLY INVERT /REVERT INTERVALS GREATER THAN 30' TVT ARE INCLUDED ON TVD PLOTS. 3. MWD RUN 1 COMPRISED DIRECTIONAL AND AT -BIT INCLINATION (ABI) WITH ELECTROMAGNETIC WAVE TELEMETRY (EM) - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS' SENSOR (DDSr). MWD RUN 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), AND GEOPILOT ROTARY - STEERABLE BHA (GP). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIRE- MENTS AT CONOCO- PHILLIPS /VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1 -3 REPRESENT WELL CD3 -122 WITH API #: 50 -103- 20609 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15,408'MD/7028'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT BIN). SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW - COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT FIXED HOLE SIZE MUD WEIGHT: 9.0 PPG • MUD SALINITY: 18,000 - 20,000 PPM CHLORIDES FORMATION WATER SALINITY: 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. 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 10/02/03 Maximum Physical Record 65535 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 2645.5 15359.5 RPX 2670.0 15366.5 RPM 2670.0 15366.5 FET 2670.0 15366.5 RPS 2670.0 15366.5 RPD 2670.0 15366.5 ROP 2695.5 15408.0 NPHI 9130.0 15319.0 NCNT 9130.0 15319.0 RHOB 9130.0 15334.0 DRHO 9130.0 15334.0 PEF 9130.0 15334.0 FCNT 9130.0 15319.0 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 2645.5 9140.0 MWD 3 9140.0 15408.0 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 Ili III 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD . G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2645.5 15408 9026.75 25526 2645.5 15408 FCNT MWD CP30 323.14 1932.22 840.026 12379 9130 15319 NCNT MWD CP30 17396.3 43974 31498.4 12379 9130 15319 RHOB MWD G /CC 0.089 2.846 2.4377 12409 9130 15334 DRHO MWD G /CC -3.985 0.201 - 0.0587744 12409 9130 15334 RPD MWD OHMM 0.2 2000 12.0124 25311 2670 15366.5 RPM MWD OHMM 0.22 1266.03 8.52154 25311 2670 15366.5 RPS MWD OHMM 0.06 1058.91 8.11026 25311 2670 15366.5 RPX MWD OHMM 0.31 29.35 7.68708 25311 2670 15366.5 FET MWD HR 0.22 120.38 1.27166 25311 2670 15366.5 GR MWD API 25.58 403.72 82.397 25429 2645.5 15359.5 PEF MWD B/E 1.33 13.05 2.12782 12409 9130 15334 ROP MWD FPH 0.62 457 113.412 25426 2695.5 15408 NPHI MWD PU 10.33 30.04 19.1541 12379 9130 15319 First Reading For Entire File 2645.5 Last Reading For Entire File 15408 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/03 Maximum Physical Record 65535 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 10/02/03 Maximum Physical Record 65535 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 SGRC 2645.5 9090.5 SFXE 2670.0 9083.0 SEXP 2670.0 9083.0 SEDP 2670.0 9083.0 SEMP 2670.0 9083.0 SESP 2670.0 9083.0 SROP 2695.5 9140.0 LOG HEADER DATA DATE LOGGED: 20- JAN -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9140.0 TOP LOG INTERVAL (FT): 2645.0 BOTTOM LOG INTERVAL (FT): 9140.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.9 MAXIMUM ANGLE: 87.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11321777 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2685.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.70 MUD VISCOSITY (S): 38.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.000 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.530 147.4 MUD FILTRATE AT MT: 2.300 72.0 MUD CAKE AT MT: 3.000 72.0 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 • i 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2645.5 9140 5892.75 12990 2645.5 9140 RPD MW,D020 OHMM 0.2 2000 7.76366 12827 2670 9083 RPM MWD020 OHMM 0.22 26.73 4.69821 12827 2670 9083 RPS MWD020 OHMM 0.06 25.61 4.55505 12827 2670 9083 RPX MWD020 OHMM 0.34 29.35 4.52424 12827 2670 9083 FET MWD020 HR 0.22 98.67 1.33738 12827 2670 9083 GR MWD020 API 34.62 403.72 115.808 12891 2645.5 9090.5 ROP MWD020 FPH 0.62 457 155.222 12890 2695.5 9140 First Reading For Entire File 2645.5 Last Reading For Entire File 9140 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/03 Maximum Physical Record 65535 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 10/02/03 Maximum Physical Record 65535 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 SGRC 9091.0 15359.5 SEXP 9125.0 15366.5 SEMP 9125.0 15366.5 SFXE 9125.0 15366.5 SEDP 9125.0 15366.5 SESP 9125.0 15366.5 SCO2 9130.0 15334.0 TNPS 9130.0 15319.0 SNP2 9130.0 15334.0 SBD2 9130.0 15334.0 CTNA 9130.0 15319.0 CTFA 9130.0 15319.0 SROP 9140.5 15408.0 LOG HEADER DATA DATE LOGGED: 31- JAN -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 15408.0 TOP LOG INTERVAL (FT): 9140.0 BOTTOM LOG INTERVAL (FT): 15408.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.4 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 261396 CTN COMP THERMAL NEUTRON 231710 EWR4 Electromag Resis. 4 11139359 ALD Azimuthal Litho -Dens 10508969 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9130.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (S): 68.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 169.6 MUD FILTRATE AT MT: .190 74.0 MUD CAKE AT MT: .200 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 t • III 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 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9091 15408 12249.5 12635 9091 15408 FCNT MWD030 CP30 323.14 1932.22 840.026 12379 9130 15319 NCNT MWD030 CP30 17396.3 43974 31498.4 12379 9130 15319 RHOB MWD030 G /CC 0.089 2.846 2.4377 12409 9130 15334 DRHO MWD030 G /CC -3.985 0.201 - 0.0587744 12409 9130 15334 RPD MWD030 OHMM 7.08 2000 16.3779 12484 9125 15366.5 RPM MWD030 OHMM 0.48 1266.03 12.4499 12484 9125 15366.5 RPS MWD030 OHMM 0.37 1058.91 11.7632 12484 9125 15366.5 RPX MWD030 OHMM 0.31 27.45 10.9368 12484 9125 15366.5 FET MWD030 HR 0.42 120.38 1.20413 12484 9125 15366.5 GR MWD030 API 25.58 85.4 48.0454 12538 9091 15359.5 PEF MWD030 B/E 1.33 13.05 2.12782 12409 9130 15334 ROP MWD030 FPH 1.99 149.8 70.4212 12536 9140.5 15408 NPHI MWD030 PU 10.33 30.04 19.1541 12379 9130 15319 First Reading For Entire File 9091 Last Reading For Entire File 15408 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/02/03 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 10/02/03 Origin STS � Tape Name UNKNOWN • • Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 10/02/03 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
