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Home My WebLink About2009 Colville River Unit2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field cc: Mr. Tom Irwin, Commissioner Alaska Department of Natural Resources 550 W. 7th Ave., Suite 800 Anchorage, AK 99501-3035 Mr. Kevin Banks, Acting Director Alaska Department of Natural Resources 550 W. 7th Ave. Suite 800 Anchorage, AK 99501 Ms. Temple Davidson, Petroleum Land Manager Alaska Department of Natural Resources 550 W. 7th Ave. Suite 800 Anchorage, AK 99501 Ms. Roberta Quintavell, President Arctic Slope Regional Corporation PO Box 129 Barrow, AK 99723-0129 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Arctic Slope Regional Corporation Attention: Land Department 3900 C Street, Suite 801 Anchorage, AK 99503-5963 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 187 Nuiqsut, AK 99789-0187 Mr. Steve Dodds, Landman Anadarko Petroleum Corporation 1201 Lake Robbins Drive The Woodlands, TX 77380 Mr. Joe Martin Anadarko Petroleum Corporation 1201 Lake Robbins Drive The Woodlands, TX 77380 2 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field 3 bcc: Warwick King ATO 1226 Gaute Naadland ATO-1770 Jack Walker ATO 1742 Brian Barreda ATO-1738 Dora Soria ATO 1468 CPAI Central Files 2009 Reservoir Surveillance Report, Alpine Oil Pool and 2009 Reservoir Review Report, Nanuq, Fiord, and Qannik Oil Pools 2009 Reservoir Surveillance Report and Reservoir March 31, 2009 Review Reports, Colville River Field Table of Contents Table of Contents .........................................................................................................................................i Alpine Oil Pool .............................................................................................................................................1 1.0 Progress of Recovery Projects............................................................................................................1 1.1 Average Metrics for 2009*...................................................................................................................1 1.2 Cumulative Volumes Produced and Injected in 2009*........................................................................1 1.3 Miscible Water Alternating Gas Flood Management During 2009 ......................................................1 CD2 .......................................................................................................................................................2 CD4 .......................................................................................................................................................2 1.4 MI Enrichment .....................................................................................................................................2 1.5 Reservoir Management .......................................................................................................................3 1.6 Water Injection Challenges .................................................................................................................3 2.0 Alpine Oil Pool Production and Injection by Month ..........................................................................4 3.0 Survey Results ......................................................................................................................................4 3.1 Reservoir Pressure Monitoring ...........................................................................................................4 3.2 Well Surveillance.................................................................................................................................4 4.0 Surveys and Survey Results................................................................................................................5 5.0 Field Development ................................................................................................................................5 5.1 Development Wells Drilled as of December 31, 2009 ........................................................................5 5.2 Development Drilling Completed in 2009............................................................................................5 5.3 Fracture Stimulations in 2009 .............................................................................................................5 5.4 Facilities Expansion ............................................................................................................................6 Alpine Water Handling Project ..............................................................................................................6 6.0 Summary ................................................................................................................................................6 Nanuq Oil Pool ............................................................................................................................................8 Overview of Reservoir Performance .........................................................................................................8 Future Development and Reservoir Depletion Plans ................................................................................8 Surveillance Information............................................................................................................................8 Fiord Oil Pool ...............................................................................................................................................9 Overview of Reservoir Performance .........................................................................................................9 Future Development and Reservoir Depletion Plans ................................................................................9 Surveillance Information............................................................................................................................9 Qannik Oil Pool .........................................................................................................................................10 Future Development and Reservoir Depletion Plans ..............................................................................10 Surveillance Information..........................................................................................................................10 Attachment 1: Colville River Unit Boundary ..........................................................................................12 i 2009 Reservoir Surveillance Report and Reservoir March 31, 2009 Review Reports, Colville River Field ii Attachment 2: All Wells Drilled as of December 31, 2009 .....................................................................13 Attachment 3: MWAG conversion status at CD1 ...................................................................................17 Attachment 4: MWAG maturity CD1 ........................................................................................................18 Attachment 5: MWAG conversion status at CD2 ...................................................................................19 Attachment 6: MWAG maturity at CD2....................................................................................................20 Attachment 7: MWAG conversion status at CD4 ...................................................................................21 Attachment 8: MWAG maturity at CD4....................................................................................................22 Attachment 9: Recovery - throughput response at Alpine ...................................................................23 Attachment 10: Alpine Form 10-412 Reservoir Pressure Report .........................................................24 Attachment 11: Nanuq Reservoir Pressure Map at Datum ...................................................................26 Attachment 12: Nanuq Form 10-412 Reservoir Pressure Report .........................................................27 Attachment 13: Nanuq Estimate of Yearly Production and Reservoir Voidage Balance ..................28 Attachment 14: Fiord Reservoir Pressure Map at Datum .....................................................................29 Attachment 15: Fiord Form 10-412 Reservoir Pressure Report ...........................................................30 Attachment 16: Fiord Estimate of Yearly Production and Reservoir Voidage Balance ....................31 Attachment 17: Qannik Reservoir Pressure Map at Datum ..................................................................32 Attachment 18: Qannik Form 10-412 Reservoir Pressure Report ........................................................33 Attachment 19: Results of Safety Valve System Testing......................................................................34 2009 Reservoir Surveillance Report Alpine Oil Pool 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Alpine Oil Pool Conservation Order 443B, Rule 8 requires this Annual Reservoir Surveillance Report. In March 2009, the Alaska Oil and Gas Conservation Commission amended the Alpine pool rules to include the Kuparuk zone in the Alpine Oil Pool with the Alpine geologic zone. These new AOGCC orders address pressure communication among the Alpine and Kuparuk zones. The AOGCC also terminated the Nanuq-Kuparuk Oil Pool and expanded the area of the Alpine Oil Pool to cover peripheral drilling plans. For this report the Alpine and Nanuq-Kuparuk will therefore be discussed in this section. Attachment 1 illustrates the current unit boundary. Attachment 2 lists wells drilled as of December 31, 2009. 1.0 Progress of Recovery Projects 1.1 Average Metrics for 2009* • Average oil production rate.......................................75.6 MBOPD • Average gas production rate.....................................98.8 MMSCFD • Average water production rate..................................9.1 MBWPD • Average gas injection rate ........................................90.3 MMSCFD • Average water injection rate .....................................115.8 MBWPD *Note: Metrics include Nanuq-Kuparuk rates. 1.2 Cumulative Volumes Produced and Injected in 2009* • Cumulative oil production through December 2009: ..........................326.8 MMSTBO • Cumulative gas production through December 2009:........................390.7 BSCF • Cumulative water production through December 2009:.....................29.4 MMSTBW • Cumulative gas injection through December 2009:............................348.5 BSCF • Cumulative water injection through December 2009:.........................348.8 MMSTB *Note: Metrics include Nanuq-Kuparuk volumes. 1.3 Miscible Water Alternating Gas Flood Management During 2009 Development of the Alpine and Nanuq-Kuparuk reservoirs are based on a Miscible Water Alternating Gas (MWAG) project design (In this Reservoir Surveillance Report, MWAG refers to a gas-alternating-water flood using either a miscible gas, or sub-miscible, enriched gas). Alpine EOR facilities have been described in previous testimony before the AOGCC. This discussion will provide a narrative update on key reservoir management issues for the time period of January 2009 through December 2009. Attachment 3 gives an overview of the miscible MWAG conversion status at CD1 in a tabular form. The MWAG flood has significantly matured at CD1, as shown in Attachment 4. CD1 averages a hydrocarbon pore volume (HCPV) throughput of approximately 97 percent amongst the 22 MWAG injectors there. Thirteen wells have completed the target MI injection volume of approximately 30 percent HCPV (CD1- 02, CD1-03, CD1-05, CD1-06, CD1-07, CD1-11, CD1-13, CD3-14, CD1-21, CD1-23, CD1-26, CD1-31, & CD1-39). Some patterns are receiving additional MI slugs, as appropriate. These are patterns in which the offset producers have competitive gas/oil ratios when the enriched gas slugs are produced. Twenty injectors have completed their second cycle of MI, after having been temporarily converted to water injection in order to alleviate rising GOR trends in offset producers. Fourteen wells have completed, or are on their third cycle of MI. Eleven wells have completed, or are on their fourth cycle of MI. Five wells have completed, or are on their fifth cycle of MI. The main drivers behind the rate of maturation of the different patterns are field offtake, local voidage balance requirements, water availability, past MI enrichment ConocoPhillips 1 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field requirements and the need to limit GORs to maximize oil production given ACF compression limits. The Alpine Water Handling Project (AWHP), discussed in 5.4, resulted in produced water going to thirteen CD1 injectors, of which, nine were on water injection in 2009. Seven CD1 wells were converted to lean gas injection in 2007 and 2008. These injectors were converted back to MWAG service in March 2009 (provided they had at least one offset producer still online); following the decision to use an enriched, sub-miscible gas for MWAG. CD2 Attachment 5 gives an overview of the MWAG conversion status in a tabular form. Attachment 6 shows the maturity of the different injection centered patterns at CD2. CD2 is significantly less mature than CD1, with only 50 percent overall through-put. This is due to a combination of factors. First, production started up later than at CD1. In addition, offtake and throughput rates at CD2 were lower due to ongoing development drilling. Finally, CD2 generally has larger pattern hydrocarbon pore volumes and poorer rock quality compared with CD1, and therefore floods at a slower pace. CD2 has thirty-five injectors. To help resolve the need for lean gas storage prior to March 2009, two CD2 injectors (CD2-06, CD2-07) were placed on lean gas WAG. With the change in header configuration, these two wells were taken off lean gas, and converted to water injection. Including the lean gas WAG as part of the gas HCPV injected, ten wells have completed the target MI injection volume of approximately 30 percent HCPV (CD2-02, CD2-06, CD2-07, CD2-08, CD2-11, CD2-12, CD2-22, CD2-26, CD2-29, & CD2-44). Twenty wells have completed, or are on their third cycle of MI. Fourteen wells have completed, or are on their fourth cycle of MI. Of the thirty-five injectors at CD2, only one has not started its first slug of MI (CD2-60) due to extremely low injectivity. CD2-60 was sidetracked in 2009 and now has greater injectivity. Overall field response to the MWAG remains excellent. Attachment 9 shows the recovery-throughput relation from all active Alpine MWAG patterns, and attests to the effectiveness of the EOR flood at Alpine. CD4 Attachment 7 gives an overview of the MWAG conversion status in a tabular form. Attachment 8 shows the maturity of the different injection centered patterns at CD4. CD4 is fairly mature relative to CD1 and CD2, with 48 percent overall through-put. However, there is significant variability in throughput rate among the CD4 wells with the Kuparuk wells generally having much higher rates than the Alpine wells. CD4 has seven Alpine Pool injectors and all of them are on or have completed their first slug of MI. Some of the Kuparuk wells have received 5-6 slugs of MI and are considered very mature while only one Alpine well has received or is on its second slug of MI. Most of the Kuparuk wells have injected more than 20% HCPV of gas with one well exceeding 30%. 1.4 MI Enrichment The enriched gas stream is manufactured at the ACF by blending lean gas from the field gas production stream (blend gas) with C2+ enriching components extracted from either the condensate flash drum (when stabilizer is offline) or the stabilizer reflux drum (when stabilizer is in operation). With the commissioning of the Gas Condensate Stabilizer Unit in December 2006, the MI enrichment process took on an added level of complexity. The stabilizer, as the name implies, stabilizes C5+ components for additional crude sales. This process reduces the amount of enriching fluid available for MI manufacture, thus impacting the overall volume of MI produced at any given MMP spec and the amount of lean gas remaining after blending. Prior to March 2009, the composition of the MI was routinely monitored and adjusted to ensure miscibility with the reservoir oils. In 2007 the amount of blend (lean) gas remaining from the MI mixing process became more than lean-gas injectors CD1-06 and CD1-14 could handle. At that point, additional CD1 wells in producing patterns were used as lean-gas injectors. This resulted in elevated gas/oil ratios in the offset producers, making the producers non-competitive on an incremental GOR basis. A type pattern model study, conducted in early 2009, indicated similar recoveries in patterns using sub-miscible gas vs. miscible gas, provided the total volume of injected enriching fluids (i.e., ethane, propane and butane) are unchanged. In order to maximize pressure support and better utilize the ConocoPhillips 2 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field gas in an EOR process, the decision was made to blend the enriched gas at a leaner ratio. In March of 2009, regulatory approval was received to inject enriched, sub-miscible gas in a WAG process. Subsequently, five injectors (CD1-02, CD1-07, CD1-11, CD1-21, and CD1-23) were taken off lean-gas injection. CD1-06 and CD1-14 remain on lean-gas, as black-start wells for startups. 1.5 Reservoir Management The Alpine Pool shares the Alpine Central Facility (ACF) production and injection facilities with the Fiord, Nanuq, and Qannik Pools. This maximizes the overall oil rate from the combined development and more fully utilizes ACF capacity. Reservoir management of the Alpine and Nanuq-Kuparuk fields in 2010 will attempt to maximize oil rate while continuing to gather strategic data associated with peripheral development opportunities. Activities supporting this effort will include: (1) targeting a pattern level injection/withdrawal ratio of one; (2) managing miscible water-alternating-gas (MWAG) injection to maximize recovery and optimize lift within ACF gas handling limits; (3) updating and ranking workover and peripheral development opportunities for optimum drilling rig utilization, and (4) identifying well stimulation candidates and hydraulically fracture stimulating up to two Alpine producers. These activities are expected to partially offset existing field decline. (In this Reservoir Surveillance Report, MWAG refers to a gas-alternating-water flood using either a miscible gas, or sub-miscible, enriched gas.) The satellite demand for ACF injection water averaged approximately 47 MBWPD in 2009. Satellite demand for water injection in 2010 is expected to be similar to 2009 (i.e., approximately 50 MBWPD). Total water production is expected to rise during the year, bringing the volume of water available for injection (produced water plus imported seawater from the GKA) above the historic water injection capacity of 150,000 BWPD. Additional manifolding and pumping capacity were installed at the ACF in 2009 to address higher than expected satellite production. These additions facilitated efforts to segregate produced water and seawater thereby reducing corrosion concerns. The new water injection capacity at the ACF is now 190,000 BWPD; however, this maximum will rarely, if ever, be achieved because of inefficiencies associated with segregated service and varying drill site demand. 1.6 Water Injection Challenges The water injection system at the ACF now consists of three 50 MBWPD centrifugal pumps and two 17 MBWPD ESP pumps. Currently, one of the centrifugal pumps takes produced water, while the rest are on seawater imported from the KRU STP. The demand for water from the seawater pumps has increased with the addition of the satellites. (Satellite water demand is higher than predevelopment estimates due to higher than expected rates from the Kuparuk reservoir at both the Nanuq and Fiord satellite fields.) The need to mitigate against corrosion in the water injection lines prevents long term mixing of all waters at Alpine and thus reduces the water injection system’s flexibility. ConocoPhillips 3 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field 2.0 Alpine Oil Pool Production and Injection by Month Production Injection Oil Gas Water Produced Water Seawater Gas Miscible Gas Total Water Total Gas DATE MSTBO MMSCF MSTBW MSTBW MSTBW MMSCF MMSCF MSTBW MMSCF 1/2009 2648.7 3891.9 663.6 755.2 2914.8 1388.4 2065.6 3670.0 3454.1 2/2009 2450.8 3536.0 627.1 648.2 2555.0 1308.8 1880.0 3203.2 3188.8 3/2009 2649.4 3791.9 715.7 557.6 3009.1 1276.5 2280.0 3566.7 3556.5 4/2009 2413.2 3387.8 760.2 658.3 2829.9 575.6 2462.9 3488.2 3038.5 5/2009 2413.7 3429.1 835.8 677.8 2887.5 246.4 2627.0 3565.3 2873.4 6/2009 2210.0 2998.2 834.2 604.9 2671.3 186.8 2631.7 3276.2 2818.5 7/2009 2070.9 2981.0 833.1 643.0 2456.8 237.3 2545.7 3099.8 2783.0 8/2009 2364.6 2978.9 999.1 719.3 2720.2 251.1 2452.1 3439.5 2703.2 9/2009 2197.3 2711.5 981.1 789.6 2497.3 230.1 2261.1 3286.9 2491.2 10/2009 2170.1 2816.3 1120.6 509.8 3140.9 240.9 1875.3 3650.7 2116.2 11/2009 2131.9 2680.3 1108.9 551.6 3291.2 219.7 1783.2 3842.8 2002.9 12/2009 2125.9 2927.0 1142.3 1027.4 3151.2 275.4 1642.2 4178.6 1917.6 3.0 Survey Results 3.1 Reservoir Pressure Monitoring Thirty-five pressure surveys were conducted on Alpine wells during the course of operations in 2009. The reservoir is continuously being managed to allow for local pressure build up in areas of historic under- injection, while maintaining average pattern pressures at or above the level required for stable production and optimum EOR performance in the rest of the field. Reservoir pressures are estimated from the Alpine full field simulation model as well as from inflow performance analyses. Both approaches are calibrated with actual reservoir pressure measurements collected from static surveys taken in development wells. In 2009 no pressure surveys were conducted on Nanuq-Kuparuk wells. The Reservoir Pressure Report (Form 10-412) for the Alpine Oil Pool is provided in Attachment 10. 3.2 Well Surveillance Twenty-four Alpine wells had reservoir pressure measured via static pressure survey in 2009. In late 2007 and early 2008, routine well surveillance uncovered numerous CD2 production wells with very significant decline rates. A significant number of these cases could be explained by pressure depletion mechanisms; however, several cases had no other explanation at the time. The potential for near-wellbore barium sulfate scale formation soon came to the forefront as a possible explanation. Historic scale monitoring efforts had mainly focused on the tubulars and surface equipment and had always pointed to a very minor tendency. A new effort was initiated early in 2008 to evaluate these suspect wells and ascertain whether or not near-wellbore scaling was occurring. Gamma-ray logs confirmed that scale was depositing in all wells exceeding five percent water cut and a few downhole samples of the barium sulfate scale were recovered. Following these discoveries, a downhole scale squeeze program was developed to treat producers in the early stages of water breakthrough. The scale inhibition program is based on the 2003- 04 Alpine core work that evaluated various scale inhibitors. Thirty-two treatments were performed on Alpine and Kuparuk wells in 2009 and a similar number are planned in 2010. Post analyses of the scale squeezes executed to date has not displayed any production impacts. ConocoPhillips 4 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field 4.0 Surveys and Survey Results There were no special surveys performed during 2009. 5.0 Field Development 5.1 Development Wells Drilled as of December 31, 2009 • 126 wells drilled total: o 22 CD1 producers o 22 CD1 injectors o 32 CD2 producers o 33 CD2 injectors o 3 CD4 Alpine producers o 3 CD4 Alpine Injectors o 4 CD4 Nanuq-Kuparuk producers o 5 CD4 Nanuq-Kuparuk injectors o 2 disposal wells 5.2 Development Drilling Completed in 2009 All Alpine wells planned for initial development from drill sites CD1 and CD2 were completed by November 2005. Since that time, peripheral opportunities have been pursued in conjunction with satellite wells. In 2006, injector CD4-17 and producer CD4-16 extended A Sand development in the southwest corner of the Alpine PA. Three wells were drilled and completed as A Sand producers in 2007: CD2-72, CD4-05 and CD4-07. CD4-05 found unexpected C Sand pay 100 ft above the A Sand and was subsequently completed in both the A Sand and C Sand. Peripheral drilling in 2008 was limited to A Sand producer CD2-75. In 2009, eight peripheral wells were drilled and completed in the APA CD1-48 (originally CD1-38 ext) was drilled as a C Sand horizontal producer. Injector CD2-60 was sidetracked to the west (parallel to CD4-16) in a successful effort to encounter better quality A Sand and subsequently improve regional A Sand pressure support. An A Sand injector/producer pair, CD2-73/CD2-74, extended field development to the northwest. Two A Sand injectors, CD2-78 and CD4-26, were drilled on the western flank of existing development. CD2-76 was drilled and completed as a C Sand slant producer. (This well originally targeted a Nechelik target, but encountered unexpected C Sand pay with elevated pressure). CD4-24 was drilled as a horizontal A Sand injector to further extend development in the southwest portion of the field. The well encountered reservoir quality A Sand in the northern portion of the wellbore (near existing development); however, sand quality was poor in the southern portion of the wellbore. CD4-24 also encountered a better than expected C Sand interval in the southern portion of the wellbore that has opened-up additional peripheral drilling opportunities. See Attachment 2 to view coordinates of all wells drilled as of December 31, 2009. No wells were drilled in the CD4 Kuparuk reservoir in 2009. 5.3 Fracture Stimulations in 2009 One Alpine well (CD2-42) was fracture stimulated in 2009 and resulted in an appreciable production rate increase. Based on fracturing success at Alpine, additional stimulations are tentatively planned for 2010. ConocoPhillips 5 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 6 5.4 Facilities Expansion Alpine Water Handling Project In September of 2009, the (AWHP) was brought online. The AWHP provided the installation of two additional water injection pumps and associated manifold tie-ins. This allowed for segregation of produced and sea water streams in the injections facilities and piping at Alpine. The overall objective of the AWHP was to provide segregated water injection distribution to each of the four existing drill sites. The project improves management of water injection for reservoir pressure support, while reducing the potential for water distribution infrastructure corrosion. However, the inability to blend produced water and seawater limits options, requiring discrete line service changes. This, in turn, results in under-injection, or over-injection, in some WNS patterns at any given time. 6.0 Summary Alpine reservoir performance remains strong and the MWAG EOR project will continue throughout 2010 based on the excellent response seen to date. Alpine drilling prospects exist at CD1, CD2 and CD4. Peripheral development areas with the most upside include the southwest (which would be primarily developed from CD4) and the east (which would be developed from CD1). CD4 prospects include two A Sand wells and up to nine C Sand wells. The A Sand wells include two producers adjacent to CD4-24. The C Sand wells target the C Sand accumulation seen in CD4-24 and an extension of the main field accumulation south of CD2-58. Performance from the Nanuq-Kuparuk reservoir has exceeded expectations. Production was initiated in November 2006 and has averaged over 18,000 BOPD since start-up. A peak rate of approximately 25,000 BOPD was achieved in October 2008, just prior to water breakthrough. Water and MI injection were initiated into the Kuparuk reservoir in December 2006 and July 2007, respectively. Both cumulative and instantaneous injection/withdrawal ratios are in the 0.9 range. Current plans are to drill one CD4 Kuparuk horizontal producer during 2010. This well will extend field development in the northeast. 2009 Reservoir Review Reports Nanuq, Fiord, and Qannik Oil Pools 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Nanuq Oil Pool Conservation Order 562, Rule 10 requires this Annual Reservoir Review Report. Overview of Reservoir Performance Nanuq production averaged 455 BOPD with a gas-oil ratio of 2105 SCF/STB and a watercut of 18%. Continuous injection was initiated in October 2009. Injection volumes in 2009 averaged 1,260 BWPD and 0.7 MMSCFPD of enriched gas. Future Development and Reservoir Depletion Plans Producer CD4-213 is planned to be drilled in 2010. Surveillance Information a. Reservoir Pressure Map at Datum: See Attachment 11, Nanuq Reservoir Pressure Map at Datum. b. Summary and Analysis of Reservoir Pressure Surveys: See Attachment 12, Nanuq Form 10-412 Reservoir Pressure Report. c. Estimate of Reservoir Pressure: The average Nanuq Oil Pool reservoir pressure was estimated to be 2600 psi. d. Results of Special Surveys: Inter-well communication was confirmed using pressure measurements. e. Estimate of yearly production and reservoir voidage balance: See Attachment 13. f. Progress of Plans and Tests to Expand the Productive Limits of the Pool: There are no plans to expand the productive limits of the Pool in 2010. g. Results of Safety Valve System Testing: See Attachment 19, Results of Safety Valve System Testing ConocoPhillips 8 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Fiord Oil Pool Conservation Order 569, Rule 9 requires this Annual Reservoir Review Report. Overview of Reservoir Performance Production from the Fiord Oil Pool averaged 24,102 BOPD at solution gas-oil ratio over 2009. The Nechelik interval began producing water late in the year and water production continued from the Kuparuk interval. Water-cuts at the end of 2009 were approximately 2% for the Nechelik interval and 37% in the Kuparuk interval. Four wells were drilled in the Fiord Oil Pool in 2009: two Nechelik wells (CD3-115 and CD3-117) and two Kuparuk wells (CD3-304 and CD3-305). The CD3-118 well was converted from pre-production to injection. The CD3-107L well was hydraulically fractured in 2009. Future Development and Reservoir Depletion Plans Development plans in the Fiord Pool include drilling five Nechelik wells (CD3-106, CD3-121, CD3-122, CD3-123, and CD3-124) and two Kuparuk sidetracks (CD3-301A and CD3-302A) in 2010. Continuation of enriched gas alternating with waterflood is also planned for 2010. The CD3-122 Nechelik well is planned to be hydraulically fractured in 2010. Surveillance Information a. Reservoir Pressure Map at Datum: See Attachment 14, Fiord Reservoir Pressure Map at Datum. b. Summary and Analysis of Reservoir Pressure Surveys: See Attachment 15, Fiord Form 10-412 Reservoir Pressure Report. c. Estimate of Reservoir Pressure: The estimate of the Fiord Oil Pool pore volume-weighted average reservoir pressure is 3268 psi at 6850’ SSTVD. d. Results of Special Surveys: Pressure responses in the Kuparuk interval suggested anisotropic permeability. e. Estimate of yearly production and reservoir voidage balance: See Attachment 16. f. Progress of Plans and Tests to Expand the Productive Limits of the Pool: Drill and log seven development wells planned during the 2010 ice road season. Evaluate open hole fracturing of the selective Nechelik producers. g. Results of Safety Valve System Testing: See Attachment 19, Results of Safety Valve System Testing ConocoPhillips 9 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Qannik Oil Pool Conservation Order 605, Rule 9 requires this Annual Reservoir Review Report. Future Development and Reservoir Depletion Plans There are no development plans for Qannik in 2010. Continuation of the CD2 Qannik waterflood is planned. Surveillance Information 1. Qannik Monthly Injection and Production Values for 2009: Qannik Injection and production for 2009 Injected Fluids (bbls) Produced Fluids (bbls) Voidage Balance (I/W) January 255413 103238 2.47 February 239378 111225 2.15 March 160265 99955 1.60 April 155338 90008 1.73 May 149133 104508 1.43 June 134939 104486 1.29 July 124965 85090 1.47 August 111652 99321 1.12 September 93202 87881 1.06 October 104037 90547 1.15 November 89683 94424 0.95 December 101753 94679 1.07 Total 1719758 1165363 1.48 2. Reservoir Pressure Map at Datum and Summary and Analysis of Reservoir Pressure: See Attachment 17, Qannik Reservoir Pressure Map at Datum and Attachment 18 for Qannik Form 10- 412 Reservoir Pressure Report. 3. Results of Qannik Production/Injection logs: No production or injection logs were run in Qannik wells during 2009. However, temperature surveys were run in Qannik producers as part of a hydrate mitigation program. ConocoPhillips 10 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 11 4. Qannik Pool Production Allocation Factors: Gas Allocation Factor Water Allocation Factor Oil Allocation Factor 1/31/2009 1.1817 1.0262 0.9573 2/28/2009 1.1660 1.0527 0.9538 3/31/2009 1.1364 0.9999 0.9434 4/30/2009 1.1368 0.9928 0.9658 5/31/2009 1.1499 0.9776 0.9725 6/30/2009 1.1551 0.9488 0.9601 7/31/2009 1.2841 0.8907 0.9194 8/31/2009 1.0805 0.9381 0.9760 9/30/2009 1.0193 0.9391 0.9827 10/31/2009 1.0050 0.8891 0.9684 11/30/2009 1.0581 0.9454 0.9794 12/31/2009 1.0874 0.9466 0.9805 5. Progress of Enhanced Recovery Project: Water injection into the Qannik reservoir was initiated during the third quarter of 2008. There is no MI or lean gas injection at Qannik. 6. Reservoir Management Summary: The current well count for the Qannik CD2 development is 9 wells (3 Injectors, 6 Producers). There are no development plans for Qannik in 2010. • 2009 oil production.......................................................... 974,700 STB (2,670 BOPD) • 2009 gas production ...................................................... 988,100 MSCF (2,707 MSCFPD) • 2009 water production .................................................... 3,900 Bbls (11 BWPD) • 2009 water injection........................................................ 1,719,700 Bbls (4,712 BWPD) 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 1: Colville River Unit Boundary ConocoPhillips 12 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 2: All Wells Drilled as of December 31, 2009 Well Name Well Service 7" Csg Shoe Start of Completion End of Completion X start Y start TD X end Y end CD1-01 INJ 7752 386226 5977656 10289 384975 5979854 CD1-02 INJ 8217 388909 5978069 12773 386773 5982084 CD1-03 INJ 7816 387016 5975903 10897 388337 5973122 CD1-04 PROD 9444 390285 5979213 13977 392388 5975199 CD1-05 INJ 10633 392065 5979111 14515 393810 5975646 CD1-06 INJ 13500 395921 5978194 16024 397043 5975933 CD1-07 INJ 13477 395838 5971681 17590 397765 5968057 CD1-08 PROD 12515 394558 5970944 15837 396091 5967999 CD1-09 PROD 11894 393604 5979402 15350 395153 5976315 CD1-10 PROD 7909 387919 5977328 11693 389639 5973962 CD1-11 INJ 12293 393432 5969790 15057 394737 5967356 CD1-12 PROD 11656 392009 5969456 13812 392938 5967515 CD1-13 INJ 8841 389949 5976723 11300 391036 5974524 CD1-14 INJ 14073 397423 5974752 18939 399752 5970483 CD1-16 INJ 9595 391456 5973711 12600 392819 5971035 CD1-17 PROD 13181 395639 5975431 18590 398233 5970693 CD1-18 PROD 11382 389206 5968235 15056 390928 5964996 CD1-20 INJ 10634 389768 5969450 16114 392499 5964709 CD1-21 INJ 9049 381896 5979206 11087 380972 5981020 CD1-229 PROD 11282 387496 5967066 16118 384021 5963708 CD1-22A PROD 8430 387229 5978470 11500 385833 5981196 CD1-23 INJ 11473 394161 5974990 14477 395504 5972306 CD1-24 PROD 10771 392946 5974121 13706 394333 5971537 CD1-25 PROD 8887 390067 5973034 12147 391614 5970167 CD1-26 INJ 8554 388729 5972343 11134 389929 5970059 CD1-27 PROD 8500 387434 5971694 11492 388770 5969018 CD1-28 PROD 7447 385821 5974802 10468 387229 5972131 CD1-30 PROD 9520 380597 5978488 12850 379073 5981447 CD1-31 INJ 10388 379306 5977679 14364 377530 5981234 CD1-32 PROD 11128 378022 5977019 14353 376466 5979841 CD1-33 INJ 7878 384485 5974129 10854 385846 5971484 CD1-34 PROD 8410 383109 5973411 11190 384448 5970977 CD1-35 PROD 8158 384636 5977159 13450 382165 5981835 CD1-36 INJ 7654 383597 5975923 10654 382248 5978601 CD1-37 INJ 9095 386283 5970682 12134 387689 5967992 CD1-38 PROD 9170 384724 5970395 12240 386139 5967673 CD1-39 INJ 10288 383468 5969466 13289 384821 5966792 CD1-40 PROD 12042 382637 5967963 15438 384188 5964948 CD1-41 PROD 8333 382239 5975220 11170 380948 5977745 CD1-42 INJ 9054 380961 5974612 11608 379729 5976849 CD1-43 PROD 10065 380436 5972089 12921 381823 5969594 CD1-44 PROD 10070 379572 5973840 12811 378332 5976283 CD1-45 INJ 9032 381802 5972762 11950 383139 5970169 CD1-46 INJ 11334 387838 5967599 15187 389598 5964174 ConocoPhillips 13 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Well 7" Csg Start of End of Well Name Service Shoe Completion Completion X start Y start TD X end Y end CD1-48 PROD 12403 16338 388864 5962736 CD2-01 PROD 12953 378098 5982112 17513 376080 5986195 CD2-02 INJ 16048 359979 5982023 21178 357334 5986377 CD2-03 PROD 13772 367096 5984984 15682 366191 5986658 CD2-03L1 PROD 13772 367096 5984984 15356 366355 5986377 CD2-05 PROD 13712 363517 5970008 16350 362341 5972367 CD2-05L1 PROD 13712 363517 5970008 17816 361740 5973701 CD2-06 INJ 9672 371098 5980645 16680 367816 5986833 CD2-07 INJ 10857 373650 5982084 14977 371786 5985755 CD2-08 INJ 12242 377278 5981611 18050 374565 5986743 CD2-09 PROD 12617 365177 5982158 16409 363411 5985509 CD2-09L1 PROD 12617 365177 5982158 16094 363566 5985235 CD2-10 PROD 10702 372139 5982079 14475 370284 5985362 CD2-11 INJ 13809 363590 5981961 18186 361601 5985856 CD2-12 INJ 8676 368889 5978303 13632 366637 5982712 CD2-13 PROD 10595 376177 5980472 14575 374339 5983995 CD2-14 PROD 7671 371963 5975571 11056 370409 5978577 CD2-15 INJ 9830 366147 5977039 14161 364157 5980881 CD2-16 INJ 9529 375989 5977320 12500 374782 5980013 CD2-17 INJ 8184 373143 5976621 8757 372880 5977130 CD2-17A INJ 8184 373143 5976621 11819 371526 5979874 CD2-18 INJ 12112 362855 5975882 18019 360209 5981156 CD2-19 PROD 8769 375572 5975101 11714 376896 5972473 CD2-20 PROD 9163 369916 5979552 14570 367451 5984361 CD2-21 PROD 13382 362791 5980234 19359 360057 5985547 CD2-22 INJ 7845 370575 5975090 11134 369051 5978002 CD2-23 PROD 9676 367151 5978351 13438 365445 5981699 CD2-24 PROD 10811 364768 5976380 14302 363212 5979502 CD2-25 PROD 8722 369286 5974237 11995 367789 5977145 CD2-26 INJ 8619 374207 5974408 11238 375406 5972081 CD2-27 INJ 12461 377930 5967068 18250 380637 5961965 CD2-28 PROD 8695 374897 5976522 13200 372799 5980502 CD2-29 INJ 9556 376873 5975841 12560 378234 5973167 CD2-30 INJ 11481 365217 5971303 15700 363306 5975062 CD2-31 PROD 13598 361069 5974966 18131 358947 5978966 CD2-32 INJ 8723 367954 5973557 11720 366579 5976218 CD2-33B PROD 9982 366697 5972759 13078 365223 5975475 CD2-34 PROD 7802 372917 5973731 8755 373366 5972891 CD2-35A INJ 9063 375633 5971746 13500 377673 5967818 CD2-36 INJ 13523 372731 5964073 17663 374634 5960399 CD2-37 PROD 14162 371725 5963095 17085 373038 5960491 CD2-38 INJ 9209 373424 5969394 13010 375164 5966019 CD2-39 PROD 9122 374692 5970192 12651 376369 5967087 CD2-40 INJ 11207 365775 5970211 14250 367117 5967484 CD2-404 INJ 5561 369454 5976682 11540 369020 5982640 CD2-41 PROD 9532 372019 5968832 13024 373637 5965742 ConocoPhillips 14 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Well 7" Csg Start of End of Well Name Service Shoe Completion Completion X start Y start TD X end Y end CD2-42 PROD 9633 367542 5970977 13138 369171 5967884 CD2-43 PROD 13106 364417 5968231 19040 367196 5962998 CD2-44 INJ 11319 378889 5972087 14555 380338 5969198 CD2-45 PROD 9972 377360 5971508 13402 378989 5968491 CD2-46 INJ 7879 371539 5973093 11000 372970 5970320 CD2-463 PROD 5149 373082 5975672 10886 372223 5981337 CD2-464 PROD 5042 372983 5972466 10776 374016 5966836 CD2-465 PROD 9642 371797 5982075 13733 372636 5986076 CD2-466 INJ 10782 369358 5983211 18286 370894 5990541 CD2-467 INJ 5399 369230 5973384 13836 370626 5965084 CD2-468 PROD 10620 366340 5981439 17850 368331 5988320 CD2-469 PROD 7396 366562 5973425 14297 366636 5980316 CD2-47 PROD 10840 369515 5967325 14580 371256 5964017 CD2-470 PROD 7940 365699 5972689 15233 366945 5965528 CD2-48 INJ 10074 370711 5968227 13622 372304 5965058 CD2-49 INJ 8891 368809 5971732 11874 370200 5969094 CD2-50 PROD 7909 370191 5972556 11624 371794 5969207 CD2-51 INJ 13246 380577 5968583 17320 382471 5964985 CD2-52 PROD 12895 379291 5967821 16881 381127 5964289 CD2-53 PROD 12394 376772 5966066 16985 378960 5962036 CD2-54 INJ 14378 361169 5970560 16617 360188 5972572 CD2-54L1 INJ 14378 361169 5970560 18250 359463 5974033 CD2-55 INJ 12210 367573 5966569 15238 368976 5963888 CD2-56 INJ 14389 362858 5967273 18027 364564 5964062 CD2-56L1 INJ 14389 362858 5967273 19554 365217 5962683 CD2-57 INJ 12642 375598 5965124 16433 377321 5961749 CD2-58 PROD 12129 373883 5965245 16389 375838 5961468 CD2-58L1 PROD 12129 373883 5965245 13550 374554 5963995 CD2-59 INJ 15743 358798 5974508 20027 357078 5978426 CD2-60 INJ 14331 369427 5962859 18695 371542 5959047 CD2-72 PROD 16693 358481 5980386 21089 356322 5984105 CD2-73 INJ 17173 357276 5979060 21810 354786 5982803 CD2-74 PROD 19125 25007 352281 5983434 CD2-75 PROD 15702 359176 5970328 23539 355431 5977153 CD2-76 PROD 12841 364691 5982544 15769 363024 5984626 CD2-78 PROD 17445 356507 5971071 23786 353433 5976520 CD3-107 PROD 11874 396088 6007547 18315 392747 6012926 CD3-107L1 PROD 11874 396088 6007547 19482 392488 6014050 CD3-108 INJ 11076 392436 6010112 18915 388364 6016746 CD3-109 PROD 9685 391206 6008984 20321 385858 6017958 CD3-110 INJ 8958 388614 6008382 17991 383533 6015832 CD3-111 PROD 8660 386239 6008068 15073 382830 6013469 CD3-111L1 PROD 8660 386239 6008068 16645 381770 6014670 CD3-112 INJ 8573 384673 6006678 16021 380471 6012813 CD3-113 PROD 9364 382985 6005331 17338 378448 6011871 CD3-114 INJ 10627 381046 6004460 18042 376886 6010589 ConocoPhillips 15 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 16 Well Name Well Service 7" Csg Shoe Start of Completion End of Completion X start Y start TD X end Y end CD3-115 PROD 12156 379712 6002482 19564 375855 6008784 CD3-117 PROD 15655 375580 6002260 21597 372375 6007239 CD3-118 INJ 13694 377632 6002202 21228 373777 6008582 CD3-301 PROD 12062 389607 6012887 15140 392226 6014458 CD3-302 INJ 8543 389856 6008066 11708 392487 6009585 CD3-303 PROD 14641 400500 6004171 14654 400512 6004173 CD3-304 PROD 17832 403555 6000171 17843 403565 6000169 CD3-305 INJ 15242 16859 401341 5997942 CD3-316A INJ 11680 396394 6003631 12515 397116 6003213 CD4-05 PROD 15140 366426 5956030 21142 363632 5961338 CD4-07 PROD 17716 363602 5962039 25040 360029 5968372 CD4-16 PROD 11664 369790 5957923 16850 367402 5962514 CD4-17 INJ 13334 368008 5957262 17975 365932 5961403 CD4-208 INJ 7314 377486 5956811 12792 375176 5961758 CD4-209 INJ 6994 377942 5955364 13215 380567 5949735 CD4-210 PROD 7470 375701 5957035 11710 373921 5960879 CD4-211 PROD 7727 376051 5955757 14379 378976 5949803 CD4-214 INJ 8696 375361 5953890 15072 378067 5948136 CD4-215 PROD 9514 374013 5953396 14761 376209 5948643 CD4-24 PROD 13566 371839 5949828 19530 369074 5954943 CD4-26 INJ 16559 365467 5952931 24749 361950 5960304 CD4-301 PROD 14855 387491 5958306 15883 389580 5956144 CD4-301A PROD 14855 387491 5958306 15431 387768 5958527 CD4-301B PROD 14855 387491 5958306 18806 386422 5962085 CD4-302 INJ 9615 384197 5956850 9626 384205 5956849 CD4-304 PROD 14610 366988 5959763 17300 366295 5962357 CD4-306 INJ 10336 372026 5960686 10346 372019 5960689 CD4-318 PROD 15047 367769 5952331 15242 367715 5952519 CD4-318A PROD 15696 367230 5952277 20612 366442 5957103 CD4-319 INJ 11993 373801 5951985 18684 372367 5958442 CD4-320 PROD 8145 378821 5957803 14471 379904 5951580 CD4-321 INJ 19323 361384 5953495 19337 361375 5953492 CD4-322 INJ 19437 360838 5959046 19452 360827 5959046 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 3: MWAG conversion status at CD1 Conversion HCPV Conversion Date HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV Conversion HCPV CD1-01 1/25/2001 5.8% 10/19/2001 4.3% 4/4/2002 7.1% 7/20/2003 6.4% 6/11/2004 5.6% 2/13/2005 4.4% 9/2/2005 8.1% 7/2/2006 4.9% 6/24/2007 6.1% 10/7/2008 1.4% 1/29/2009 4.3%CD1-02 2/7/2001 9.8% 12/21/2001 11.1% 7/19/2002 9.9% 10/30/2003 5.9% 7/3/2004 3.8% 11/23/2004 5.4% 6/3/2005 10.2% 4/24/2006 4.4% 1/10/2007 1.6% 7/24/2007 12.4% 4/12/2009 0.1%CD1-03 4/10/2001 14.8% 6/5/2002 16.3% 7/19/2003 7.0% 12/19/2003 4.6% 4/29/20046.3% 11/23/2004 6.6% 6/2/2005 8.5% 12/15/2005 4.7% 5/25/2006 16.4% 1/16/2008 12.6% 4/16/2009 1.6% 8/16/2009 2.7%CD1-05 1/1/2001 49.1% 6/23/2002 62.4% 6/21/2007 12.7%CD1-06 12/13/2000 285.1%CD1-07 7/13/2004 19.3% 4/11/2005 15.1% 11/22/2005 8.5% 4/2/2006 8.6% 8/29/2006 13.8% 1/23/2007 8.3% 5/23/2007 10.5% 1/16/2008 4.8% 6/19/2008 0.5% 7/26/2008 4.6% 4/20/2009 6.4%CD1-11 1/26/2005 16.5% 8/27/2005 11.1% 12/13/2005 7.8% 3/31/2006 10.1% 9/3/2006 12.9% 4/5/2007 10.9% 11/17/2007 11.1% 4/20/2009 9.0% 1/23/2010 1.2%CD1-13 1/25/2001 10.4% 11/22/2001 17.1% 11/17/2002 12.2% 10/30/2003 4.7% 6/12/2004 5.6% 4/11/2005 3.9% 10/4/2005 7.7% 8/31/2006 3.1% 3/2/2007 3.8% 3/11/2008 3.4%CD1-14 9/4/2001 42.2% 2/1/2002 112.6% 4/2/2005 3.1% 4/26/2005 116.8% 6/24/2007 61.0%CD1-16 3/8/2001 13.7% 11/16/2002 12.6% 7/3/2004 5.4% 6/3/2005 6.6% 4/1/2006 9.6% 3/25/2007 4.6% 12/11/2007 6.2% 11/10/2008 3.3% 4/12/2009 2.5% 10/19/2009 2.0%CD1-20 1/23/2005 14.7% 1/14/2006 11.6% 4/1/2007 11.0% 8/27/2008 2.7% 12/6/2008 3.4% 5/23/2009% 2.8% 10/1/2009% 2.9%CD1-21 3/10/2001 12.3% 11/7/2001 22.3% 7/19/2003 4.1% 12/17/2003 4.1% 6/12/2004 4.6% 6/3/2005 3.5% 12/14/2005 11.2% 7/24/2007 15.2% 6/16/2009 1.8% 6/16/2009 4.2%CD1-23 3/30/2001 18.8% 4/3/2002 28.5% 7/20/2003 15.0% 10/3/2004 6.7% 4/12/2005 37.4% 1/16/2008 6.7% 4/20/2009% 3.8%CD1-26 1/25/2001 18.8% 7/26/2002 14.2% 9/19/2003 14.0% 1/16/2005 6.4% 10/5/2005 6.0% 3/29/2006 7.4% 1/10/2007 7.7% 12/13/2007 2.7% 6/10/2008 3.9% 4/24/2009 2.7% 11/2/2009 2.0%CD1-31 12/13/2000 18.3% 10/6/2001 22.6% 10/21/2003 2.8% 4/29/2004 5.6% 2/13/2005 8.0% 3/29/2006 5.0% 12/9/2006 1.1% 3/31/2007 10.0% 4/24/2009 3.0% 10/9/2009 2.9%CD1-33 2/18/2001 12.6% 11/29/2002 10.8% 7/5/2004 4.4% 6/24/2005 8.3% 12/9/2006 8.7% 4/24/2009 1.3% 8/16/2009 1.9%CD1-36 1/25/2001 17.8% 7/19/2003 12.5% 1/16/2005 4.6% 1/13/2006 6.9% 3/2/2007 7.2% 12/12/2008 1.6% 4/14/2009 3.4%CD1-37 2/20/2001 20.2% 6/23/2002 13.8% 7/21/2003 8.2% 1/16/2005 8.4% 2/2/2007 10.5% 2/23/2009 2.7% 11/9/2009% 1.3%CD1-39 1/25/2001 22.4% 6/25/2003 21.1% 9/19/2003 10.1% 10/31/2004 9.1% 12/4/2005 17.9% 5/20/2008 3.2% 11/8/2008 3.2% 5/23/2009% 2.8% 10/26/2009 2.0%CD1-42 1/25/2001 12.0% 2/28/2002 20.0% 9/19/2003 7.0% 10/31/2004 3.2% 7/8/20058.8% 9/27/2006 2.5% 3/16/2007 5.7% 3/11/2008 3.3% 11/9/2008 4.2% 12/6/2009 0.2% 12/31/2009 0.8%CD1-45 2/2/2001 15.6% 2/10/2003 8.7% 7/6/2004 5.5% 6/7/2005 7.8% 12/18/2006 6.0% 6/10/2008 3.6% 6/26/2009 1.8%CD1-46 8/28/2004 18.5% 12/10/2005 8.5% 1/10/2007 7.9% 12/10/2007 3.7% 9/6/2008 3.8% 4/24/2009 3.1% 10/3/2009 4.7% 1/9/2010 1.1%Nomenclature: SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injectionAlpine MWAG Status - CD113th Cycle12th Cycle10th Cycle11th Cycle8th CycleWell9th Cycle4th Cycle5th Cycle6th Cycle7th Cycle1st Cycle2nd Cycle3rd Cycle ConocoPhillips 17 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 4: MWAG maturity CD1 CD1 MWAG Status0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% 110% 120% 130% 140% 150% 160%CD1-01CD1-02CD1-03CD1-05CD1-06CD1-07CD1-11CD1-13CD1-14CD1-16CD1-20CD1-21CD1-23CD1-26CD1-31CD1-33CD1-36CD1-37CD1-39CD1-42CD1-45CD1-46Cum HCPVI (%)SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injection ConocoPhillips 18 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 5: MWAG conversion status at CD2 Conversion DateHCPV Injected Conversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedCD2-02 12/30/2005 23.5% 12/4/2006 11.2% 11/20/2007 13.1% 5/5/2008 5.7% 7/23/2008 13.8% 11/25/2008 6.7% 2/25/2009 11.8% 6/6/2009 4.5% 9/11/2009 9.1% 12/5/2009 2.9%CD2-06 11/10/2003 19.2% 10/30/2004 11.0% 6/23/2005 13.4% 3/20/2006 10.3% 10/31/2006 6.2% 3/30/2007 2.9% 8/29/2007 2.0% 11/18/2007 6.8% 4/9/2008 3.1% 7/20/2008 4.1% 11/24/2008 15.2%CD2-07 2/6/2004 23.8% 2/11/2005 12.1% 8/25/2005 10.6% 11/19/2005 10.6%3/17/2006 13.8% 8/27/2006 12.3% 1/27/2007 17.0% 8/31/2007 10.9% 11/16/2007 9.3% 3/31/2008 12.3% 7/21/2008 9.7% 11/27/2008 5.4% 1/21/2009 33.9%CD2-08 3/25/2003 13.4% 3/28/2004 13.5% 2/12/2005 13.3% 3/24/2006 11.1%2/9/2007 5.1% 7/30/2007 5.0% 3/18/2008 14.6% 6/7/2009 2.8% 10/24/2009 4.7%CD2-11 2/9/2006 16.0% 5/27/2006 16.7% 12/5/2006 14.6% 4/12/2007 13.2%11/17/2007 25.4% 12/8/2008 6.4% 3/19/2009 5.6% 6/15/2009 4.1% 7/10/2009 5.9%CD2-12 6/25/2003 24.6% 10/3/2004 13.8% 6/22/2005 4.6% 12/8/2005 10.5% 6/28/2006 8.0% 1/2/2007 5.9% 7/20/2007 16.6% 6/15/2009 3.9% 10/16/2009 4.9%CD2-15 2/24/2002 11.7% 8/6/2003 14.5% 4/9/2005 5.9% 1/11/2006 1.8% 4/22/2006 6.7% 4/8/2007 5.5% 4/9/2008 4.7% 6/8/2009 2.6%CD2-16 9/25/2002 9.2% 12/19/2003 9.8% 2/15/2005 4.9% 8/27/2005 5.2% 3/21/2006 5.7% 11/2/2006 6.4% 11/12/2007 5.8% 12/8/2008 4.3% 6/27/2009 5.0%CD2-17 3/5/2002 11.1% 10/30/2003 6.9% 10/30/2004 8.9% 4/24/2006 9.3% 7/20/2007 7.8% 6/27/2008 4.4% 3/19/2009 5.0% 10/15/2009 2.6%CD2-18 10/30/2003 14.8% 9/3/2006 3.7% 5/25/2007 4.6% 1/15/2008 3.5% 8/1/2008 3.7% 2/12/2009 3.5% 10/31/2009 1.1%CD2-22 6/8/2002 13.5% 9/22/2003 15.1% 2/8/2005 6.1% 8/27/2005 7.8% 3/24/2006 9.1% 12/27/2006 8.6% 10/22/2007 19.0% 6/18/2009 2.9% 10/24/2009 3.4%CD2-26 2/22/2002 15.0% 7/23/2003 14.8% 4/9/2005 5.7% 12/12/2005 12.2%8/2/2007 11.7% 7/17/2008 2.7% 11/23/2008 4.5% 6/27/2009 3.3% 12/5/2009 2.5%CD2-27 1/8/2004 15.0% 5/24/2006 7.5% 11/16/2007 7.1% 5/17/2009 2.8% 12/22/2009 1.6%CD2-29 10/30/2002 8.9% 10/10/2003 13.4% 2/14/2005 5.7% 9/3/2005 5.5% 2/14/2006 9.8% 12/26/2006 8.1% 10/5/2007 8.6% 6/27/2008 3.2% 12/6/2008 8.5% 12/5/2009 1.5%CD2-30 2/3/2004 14.4% 2/12/2007 6.0% 9/13/2008 3.8%CD2-32 3/31/2002 12.7% 9/23/2003 9.6% 7/7/2005 10.6% 3/11/2007 4.6% 5/17/2008 5.1% 5/9/2009 2.5%CD2-35 4/26/2003 12.2% 4/29/2005 7.9% 5/20/2006 6.9% 7/30/2007 5.5% 7/14/2008 10.7%CD2-36 4/28/2003 16.5% 6/4/2005 10.3% 4/26/2006 8.3% 6/13/2007 0.0% 2/12/2008 12.9%CD2-38 10/17/2002 12.3% 4/29/2005 8.6% 9/24/2006 4.2% 10/22/2007 3.7% 9/3/2008 6.2% 1/2/2010 0.6%CD2-40 9/20/2003 12.1% 3/16/2007 2.7% 7/22/2008 4.1%CD2-44 10/22/2002 14.3% 9/21/2003 11.3% 7/9/2004 10.2% 2/15/2005 9.5%10/25/2005 9.7% 7/2/2006 11.2% 6/10/2007 18.0% 5/9/2009 3.1% 11/9/2009 2.3%CD2-46 5/30/2002 10.7% 6/10/2004 6.6% 7/7/2005 10.1% 12/13/2006 6.0% 2/8/2008 6.2% 4/15/2009 3.6%CD2-48 7/19/2002 9.3% 10/2/2004 9.0% 10/30/2006 11.4%CD2-49 2/22/2002 4.0% 10/11/2002 4.2% 4/17/2003 1.4% 10/22/2003 4.6%6/4/2005 5.7% 12/23/2006 5.2% 8/1/2008 0.0% 10/12/2008 1.7% 11/6/2009 0.7%CD2-51 7/4/2003 16.6% 12/5/2005 12.3% 8/17/2007 13.1% 9/11/2009 3.0%CD2-54 11/24/2004 20.4% 3/27/2006 2.7% 10/17/2006 6.1% 6/14/2007 4.7% 5/2/2008 6.0% 9/4/2008 1.0% 1/21/2009 1.8% 8/19/2009 0.4% 11/19/2009 3.9%CD2-55 12/23/2003 10.8% 5/19/2008 2.7% 6/18/2009 1.3%CD2-56 11/19/2004 13.6% 11/12/2007 3.5% 5/17/2008 4.1% 12/8/2008 1.9% 2/12/2009 8.1%CD2-57 6/23/2004 13.7% 11/2/2006 6.0% 5/23/2008 6.5% 11/20/2009 1.4%CD2-59 11/20/2005 14.3% 2/27/2007 6.4% 5/1/2008 6.5% 12/8/2008 3.4% 2/24/2009 0.3% 8/19/2009 3.1% 11/14/2009 5.2%CD2-60 1/26/2006 4.4%CD2-73 10/2/2009 6.6% 1/8/2010 3.2%Nomenclature: SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injectionAlpine MWAG Status - CD213th Cycle12th Cycle10th Cycle11th CycleWell1st Cycle2nd Cycle3rd Cycle9th Cycle4th Cycle5th Cycle6th Cycle7th Cycle8th Cycle ConocoPhillips 19 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 6: MWAG maturity at CD2 CD2 MWAG Status0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% 110% 120% 130% 140% 150% 160%CD2-02CD2-06CD2-07CD2-08CD2-11CD2-12CD2-15CD2-16CD2-17CD2-18CD2-22CD2-26CD2-27CD2-29CD2-30CD2-32CD2-35CD2-36CD2-38CD2-40CD2-44CD2-46CD2-48CD2-49CD2-51CD2-54CD2-55CD2-56CD2-57CD2-59CD2-60CD2-73Cum HCPVI (%)SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injection ConocoPhillips 20 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 7: MWAG conversion status at CD4 Nanuq KuparukConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedCD4-302 1/0/1900 13.3% 1/0/1900 0.0% 1/0/1900 7.2% 1/0/1900 10.8% 1/0/1900 13.0% 1/0/1900 6.2% 1/0/1900 6.4% 1/0/1900 5.9% 1/0/1900 4.0% 1/0/1900 1.5% 1/0/1900 5.5%CD4-306 8/8/2007 6.5% 1/27/2008 7.2% 5/19/2008 6.1% 10/12/2008 7.2% 1/25/2009 7.2% 7/12/2009 3.7% 9/13/2009 4.8% 1/17/2010 2.1%CD4-319 12/2/2006 17.9% 10/7/2007 6.7% 12/7/2007 4.1% 3/8/2008 6.6% 6/8/2008 6.0% 10/8/2008 5.7% 12/8/2008 4.9% 3/19/2009 7.2% 6/14/2009 6.6% 10/23/2009 2.4% 12/14/2009 5.1%CD4-321 12/22/2006 12.4% 7/21/2007 5.8% 10/7/2007 5.5% 12/28/2007 9.4% 4/15/2008 6.3% 7/18/2008 8.1% 10/31/2008 6.3% 1/25/2009 6.1% 3/27/2009 5.7% 6/8/2009 4.9% 8/8/2009 10.9% 12/21/2009 3.7% 1/25/2010 2.9%CD4-322 9/10/2007 3.6% 1/8/2008 5.4% 7/8/2008 3.9% 12/8/2008 1.5% 3/30/2009 3.8% 8/8/2009 2.8% 12/6/2009 0.9%Nomenclature: SW Sea water injectionMI Miscible gas injectionDry GasDry gas injectionConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedConversion DateHCPV InjectedCD4-17 3/12/2007 13.3% 2/13/2008 5.2% 2/25/2009 11.5% 2/12/2010 0.3%CD4-26 2/10/2009 6.2% 2/21/2010% 0.1%Nomenclature: SW Sea water injectionMI Miscible gas injectionDry GasDry gas injection12th Cycle13th Cycle8th Cycle9th Cycle10th Cycle11th Cycle4th Cycle5th Cycle6th Cycle7th CycleWell1st Cycle2nd Cycle3rd CycleWell1st CycleAlpine MWAG Status - CD46th Cycle7th Cycle2nd Cycle3rd Cycle4th Cycle5th CycleConocoPhillips 21 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 8: MWAG maturity at CD4 Nanuq Kuparuk MWAG Status0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% 110% 120% 130% 140% 150% 160%CD4-302CD4-306CD4-319CD4-321CD4-322Cum HCPVI (%)SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injectionCD4 Alpine MWAG Status0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% 110% 120% 130% 140% 150% 160%CD4-17CD4-26Cum HCPVI (%)SW Sea water injectionMI Miscible gas injectionDry Gas Dry gas injection ConocoPhillips 22 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 9: Recovery - throughput response at Alpine 01020304050607080901000.00.10.20.30.40.50.60.70.80.91.0Injected Volume (fraction HCPV)Oil Recovery (%OOIP)TPMWater BTGas BTCD1CD2"TPM" Refers ToType Pattern Model ConocoPhillips 23 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 11: Nanuq Reservoir Pressure Map at Datum ConocoPhillips 26 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 13: Nanuq Estimate of Yearly Production and Reservoir Voidage Balance ConocoPhillips 28 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 14: Fiord Reservoir Pressure Map at Datum ConocoPhillips 29 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 16: Fiord Estimate of Yearly Production and Reservoir Voidage Balance Basis: Initial Solution GOR = 520 Scf/STBO Initial Oil Formation Volume Factor (FVF) =1.3 RBO/STBO Water FVF = 1.01 RBW/STBW ConocoPhillips 31 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 17: Qannik Reservoir Pressure Map at Datum ConocoPhillips 32 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Attachment 19: Results of Safety Valve System Testing Date: 1/11/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-36 1991120 1850 1848 P P 9GINJWells:13Failure1Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: Seth BrowerField/Unit/Pad: Alpine / CRU / CD1 MISCRemarks:Lou with AOGCC was here for the CD3 testing and waved the Misc pad testing.AOGCC Rep: Waived Separator psi:Well DataPilotsCD1-36 SSSV scheduled for serviceOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 34 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 01/16/09LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-36 1991120 1850 NT NT PGINJWells:11Failure0Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: Seth BrowerField/Unit/Pad: Alpine / CRU / CD1 RETESTRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 35 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/07/09Alpine / CRU / CD1LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-02 2001720 1850 1840 P P PGINJCD1-03 1991200 1850 1835 P P PGINJCD1-05 1991280 1850 1840 P P 9GINJCD1-06 2000830 1850 1842 P P 9GINJCD1-08 2040590 150 100 97 P P POILCD1-12 2042050 150 100 97 P P POILCD1-13 1990520 1850 1829 P P PGINJCD1-14 2010380 1850 1831 P P PGINJCD1-16 1990940 1850 1845 P P PGINJCD1-17 2001450 150 100 95 P P POILCD1-18 2042060 150 100 97 P P 9OILCD1-21 2010060 1850 1835 P P PGINJCD1-24 1990260 150 100 98 P P POILCD1-25 2000080 150 100 95 P P POILCD1-27 2000060 150 100 96 P P 9OILCD1-28 2001990 150 100 95 P P POILCD1-32 1991040 150 100 85 P P POILCD1-34 2000430 150 100 99 P P 9OILCD1-35 1990380 150 100 97 P P 9OILCD1-36 1991120 1850 1838 P P PGINJCD1-37 1990670 1850 1838 P P 9GINJCD1-38 2000030 150 100 97 P P POILCD1-40 1990440 150 100 98 P P 9OILCD1-41 2000170 150 100 99 P P 9OILCD1-43 2001060 150 100 99 P 4 P03/07/09 OILCD1-44 2000550 150 100 100 P P POILCD1-45 1991010 3900 1850 1850 P P PWAGWells:2781Failure1012.35%CD1-43 SSV was serviced and passed retest on 03/07/09Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:All Failed SSSV's have been scheduled for servicingAOGCC Rep: Jeff Jones Separator psi:Well DataPilotsOperator Rep: G.PetersonField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 36 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/09/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-43 2001060NT P NTOILWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 37 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/18/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-05 1991280NT NT PGINJWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 38 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/19/09Alpine / CRU / CD1 MISCLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-48 2090010 153 100 98 P P POILWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: D. DigulimioField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Ligenza90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 39 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/19/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-34 2000430 150NT NT POILCD1-40 1990440 150NT NT POILWells:22Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 40 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/20/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-41 2000170 150NT NT POILWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 41 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/21/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-35 1990380 150NT NT POILWells:11Failure0Operator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. AlexanderRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 42 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/22/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-06 2000830NT NT PGINJCD1-18 2042060 150NT NT POILWells:22Failure0Operator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. AlexanderRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 43 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 03/24/09Alpine / CRU / CD1 RETESTLPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-27 2000060 150NT NT POILCD1-37 1990670NT NT PGINJWells:22Failure0Operator Rep: G.PetersonField/Unit/Pad:Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: R. AlexanderRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 44 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/3/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-33 2002120 1850 1845 P P 905/15/09 GINJWells:13Failure1Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD1 MISCOperator Rep: AndrusRemarks:5/15/09 Wire Line replaced A1 Injection vave. Good closure test.AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 45 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/4/2009LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-26 1990880 1850 1840 P P PGINJWells:13Failure0Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD1 MISCOperator Rep: AndrusRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 46 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/5/2009LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-31 2001180 1850 1835 P P 905/16/09 GINJWells:13Failure1Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:Wire line replaced A1 injection valve. Good closure test.AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD1 MISCOperator Rep: Andrus90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 47 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 48 Date: 5/17/2009LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-46 2040240 1850 1848 P P PGINJWells:13Failure0Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD1 MISCOperator Rep: Seth BrowerRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 6/10/2009 LPS 155 HPS SSV SSSV Retest/SI Date Well Type Well Permit Separ Set L/P Test Test Test Date Passed Retest Number Number PSI PSI Trip Code Code Code Or Date Shut In CD1-02 2001720 04/12/09 SI CD1-03 1991200 1850 1820 P P P GINJ CD1-04 2001170 08/29/08 SI CD1-05 1991280 04/12/09 SI CD1-06 2000830 1850 1850 P P P GINJ CD1-08 2040590 155 100 99 P P P OIL CD1-09 2000710 07/18/08 SI CD1-10 2001710 08/19/07 SI CD1-12 2042050 155 100 98 P P P OIL CD1-13 1990520 04/14/09 SI CD1-14 2010380 1850 1840 P P P GINJ CD1-17 2001450 06/06/09 SI CD1-18 2042060 155 100 98 P P P OIL CD1-20 2042400 1850 1820 P P P GINJ CD1-21 2010060 1850 1830 P P P GINJ CD1-229 2002150 05/10/06 SI CD1-22A 2001100 12/12/08 SI CD1-24 1990260 155 100 99 P P 9 OIL CD1-25 2000080 155 100 98 P P 9 OIL CD1-26 1990880 1850 1830 P 4 9 06/09/09 GINJ CD1-27 2000060 155 100 100 P P P OIL CD1-28 2001990 155 100 100 P P P OIL CD1-30 2001320 12/01/07 SI CD1-31 2001180 1850 1840 P P P GINJ CD1-32 1991040 155 100 100 P P P OIL CD1-33 2002120 1850 1810 P P P GINJ CD1-34 2000430 155 100 100 P P 9 OIL CD1-35 1990380 155 100 100 P P P OIL CD1-37 1990670 1850 1820 P P P GINJ CD1-38 2000030 155 100 98 P P P OIL CD1-39 1990800 1850 1840 P P P GINJ CD1-40 1990440 155 100 97 P P P OIL CD1-41 2000170 155 100 96 P P 9 OIL CD1-43 2001060 155 100 97 P P P OIL CD1-44 2000550 155 100 98 P P P OIL CD1-45 1991010 1850 1840 P P P GINJ CD1-46 2040240 1850 1850 P P 9 06/15/09 GINJ CD1-48 2090010 155 100 100 P P P OIL Wells:28 84 Failure 7 8.33% Chuck Sheve said they were unable to witness SVS testing this month. Field/Unit/Pad: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillips Submitted By: Rich Ligenza Alpine/ CRU / CD1Operator Rep: Rick Alexande Remarks: AOGCC Rep: Waived Separator psi: Well Data Pilots Wells CD1-14, 20, 21, 26, 31, 39, & 45 were tested on 06/09/09 CD1-26 SSV was serviced and passed retest on 06/09/09, SSSV scheduled for repai Well CD1-06 was tested on 06/10/09 Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 49 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 50 Date: 09/07/09 LPS 150 HPS SSV SSSV Retest/SI Date Well Type Well Permit Separ Set L/P Test Test Test Date Passed Retest Number Number PSI PSI Trip Code Code Code Or Date Shut In CD1-06 2000830 1850 1820 P P P GINJ CD1-08 2040590 150 100 112 P P P OIL CD1-12 2042050 150 100 100 P P P OIL CD1-14 2010380 1850 1800 P P P GINJ CD1-18 2042060 150 100 88 P P P OIL CD1-20 2042400 1850 1830 P P P GINJ CD1-24 1990260 150 100 96 P P P OIL CD1-25 2000080 150 100 99 P P P OIL CD1-26 1990880 1850 1840 P P P GINJ CD1-27 2000060 150 100 98 P P P OIL CD1-28 2001990 150 100 96 P P P OIL CD1-31 2001180 1850 1850 P P P GINJ CD1-32 1991040 150 100 97 P P P OIL CD1-34 2000430 150 100 105 P P P OIL CD1-35 1990380 150 100 97 P P P OIL CD1-37 1990670 1850 1850 P P P GINJ CD1-38 2000030 150 100 97 P P P OIL CD1-39 1990800 1850 1841 P P P GINJ CD1-40 1990440 150 100 96 P P P OIL CD1-41 2000170 150 100 97 P P 8 09/19/09 OIL CD1-43 2001060 150 100 95 P P P OIL CD1-44 2000550 150 100 96 P P 9 09/20/09 OIL CD1-46 2040240 1850 1840 P P P GINJ CD1-48 2090010 150 100 97 P P P OIL Wells:25 72 Failure 2 2.78% CD-44 Retest passed 09-20-09 CPAI witness Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate: Remarks:CD1-41 Retest passed 09-19-09 CPAI witness AOGCC Rep: Bob Noble Separator psi: Well Data Pilots Operator Rep: Craig DiamonField/Unit/Pad: Alpine / CRU / CD1 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillip Submitted By: Rich Ligenza 90 Day 90 Day 90 Day 90 Day 90 Day 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 12/27/2009LPS 164HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD1-04 2001170 164 100 100 P P 9OILCD1-42 1991190 1850 1850 P P 8GINJWells:26Failure2Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Mike GravesField/Unit/Pad: Alpine/ CRU / CD1 MISCRemarks:CD1-04 SSSV scheduled for service.AOGCC Rep: Waived Separator psi:Well DataPilotsCD1-42 SSSV scheduled for service.Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 51 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 1/11/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-11 2051320 1850 1845 P P PGINJCD2-16 2021440 1850 1848 P P PGINJCD2-464 2080820 150 100 98 P P POILWells:39Failure0Lou with AOGCC was here for the CD3 testing and waved the Misc pad testing.Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: GravesField/Unit/Pad: Alpine / CRU / CD2 MISCAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 52 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 53 Date: 02/02/09LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-468 208180 150 100 103 P P POILCD2-469 2081220 150 100 101 P 4 P02/04/09 OILCD2-52 2030930 150 100 100 P P POILCD2-59 2042480 1850 1800 P P PGASWells:412Failure1Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: QuigleyField/Unit/Pad: Alpine / CRU / CD2 MISCRemarks:CD2-469 SSV was seviced and passed on 02/04/09AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/13/2009 LPS 157 HPS SSV SSSV Retest/SI Date Well Type Well Permit Separ Set L/P Test Test Test Date Passed Retest Number Number PSI PSI Trip Code Code Code Or Date Shut In CD2-01 2051180 157 100 95 P P 9 OIL CD2-03 2050920 157 100 97 P 4 P 03/13/09 OIL CD2-05 2040970 157 100 97 P P P OIL CD2-09 2041290 157 100 95 P 4 9 03/13/09 OIL CD2-11 2051320 1850 1830 P P P GINJ CD2-13 2022030 157 100 98 P P P OIL CD2-14 2011770 157 100 90 P P P OIL CD2-16 2021440 1850 1830 P P P GINJ CD2-17A 2050170 1850 1830 P P P GINJ CD2-18 2031510 1850 1850 P P P GINJ CD2-19 2021120 157 100 95 P P P OIL CD2-20 2031050 157 100 97 P P P OIL CD2-21 2042450 157 100 95 P P P OIL CD2-23 2021340 157 100 90 P P P OIL CD2-25 2020740 157 100 100 P P P OIL CD2-28 2022170 157 100 90 P P P OIL CD2-31 2040820 157 100 95 P P P OIL CD2-34 2011910 157 100 100 P P P OIL CD2-37 2022110 157 100 95 P P P OIL CD2-39 2011600 157 100 96 P P 9 OIL CD2-41 2021260 157 100 100 P P P OIL CD2-42 2010670 157 100 95 P P 9 OIL CD2-43 2031970 157 100 97 P P P OIL CD2-45 2012120 157 100 98 P P P OIL CD2-47 2012050 157 100 95 P P P OIL CD2-50 2020490 157 100 95 P P P OIL CD2-52 2030930 157 100 97 P P P OIL CD2-53 2040890 157 100 95 P P P OIL CD2-55 2031180 1850 1790 P P P GINJ CD2-58 2030850 157 100 98 P P P OIL CD2-463 2081070 157 100 90 P P P OIL CD2-464 2082820 157 100 95 P P P OIL CD2-468 2081800 157 100 90 P P P OIL CD2-464 2082820 157 100 90 P P P OIL CD2-470 2081290 157 100 98 P P P OIL CD2-72 2070570 157 100 90 P P 9 OIL CD2-75 2080640 157 100 100 P P P OIL Wells:37 111 Failure 7 6.31% CD2-03 SSV was serviced and passed retested on 03-13-09 AOGCC witnessed CD2-09 SSV was serviced and passed retest on 03/13/09 Listed failed SSSV's have been scheduled for servicing. Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate: Remarks:Wells CD2-01 to CD2-34 tested on 03-12-09, CD2-35 to CD2-75 tested on 03-13-09 AOGCC Rep: Chuck Scheve Separator psi: Well Data Pilots Field/Unit/Pad: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillip Submitted By: Rich Ligenza Alpine/ CRU / CD2Operator Rep: Mike Mishler 90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 54 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/14/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-33B 2011250 157 100 100 P P POILWells:13Failure0Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Mike MishlerField/Unit/Pad: Alpine/ CRU / CD2 MISCRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 55 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/20/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-24 2010950 157 100 100 P P POILWells:13Failure0Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Mike MishlerField/Unit/Pad: Alpine/ CRU / CD2 MISCRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 56 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/23/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-01 2051180 157 100 NT NT POILCD2-09 2041290 157 100 NT NT POILWells:22Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Alpine/ CRU / CD2 RETESTRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Mike MishlerField/Unit/Pad:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 57 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/24/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-42 2010670 157 100 NT NT POILCD2-72 2070570 157 100 NT NT POILWells:22Failure0Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD2 RETESTRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: Mike MishlerOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 58 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 3/25/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-39 2011600 157 100 NT NT POILWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Alpine/ CRU / CD2 RETESTRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Mike MishlerField/Unit/Pad:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 59 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/10/2009LPS 157HPS N/ASSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-10 2031950 157 100 100 P P POILCD2-46 2020820 1850 1840 P P PGINJWells:26Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipsSubmitted By: Rich LigenzaAlpine/ CRU / CD2 MISCOperator Rep: Mike Graves90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 60 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/16/2009LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-32 2020290 1850 1850 P P PGINJCD2-44 2021650 1850 1850 P P PGINJCD2-49 2012490 1850 1850 P P PGINJWells:39Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipsSubmitted By: Rich LigenzaAlpine/ CRU / CD2 MISCOperator Rep: Mike Mishler90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 61 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 6/12/2009LPS 155HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-02 2051090 1850 1850 P P PGINJCD2-10 2031950 150 100 100 P P POILCD2-27 2031770 1850 1850 P P PGINJCD2-46 2020820 1850 1850 P P PGINJCD2-465 2081450 150 100 100 P P POILWells:515Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:Chuck Sheve said they were unable to witness SVS testing this month.AOGCC Rep: waived Separator psi:Well DataPilotsOperator Rep: Seth BrowerField/Unit/Pad: Alpine/ CRU / CD2 MISCAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich Ligenza90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 62 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 08/09/09LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-74 2081970 150 100 98 P P 908/10/09 OILWells:13Failure1Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: AlexanderField/Unit/Pad: Alpine/ CRU / CD2 MISCRemarks:CD2-74 was sreviced and passed retest on 08-10-09AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 63 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 64 Date: 08/23/09LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-08 2022500 1850 1840 P P PGINJCD2-12 2030730 1850 1840 P P PGINJCD2-15 2011590 1850 1850 P P PGINJCD2-22 2020920 1850 1840 P P PGINJCD2-26 2012320 1850 1830 P P PGINJWells:515Failure0Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: AlexanderField/Unit/Pad: Alpine/ CRU / CD2 MISCRemarks:Chuck Sheeve waived the State witnessAOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 09/05/09 LPS 155 ps HPS SSV SSSV Retest/SI Date Well Type Well Permit Separ Set L/P Test Test Test Date Passed Retest Number Number PSI PSI Trip Code Code Code Or Date Shut In CD2-01 2051180 155 100 98 P P 9 Retest pass 09-17-09 C OIL CD2-02 2051090 1850 1869 P P P GINJ CD2-03 2050920 155 100 95 P P P OIL CD2-05 2040970 155 100 98 P P P OIL CD2-08 2022500 1850 1800 P P P GINJ CD2-09 2041290 155 100 99 P P P OIL CD2-10 2031950 155 100 100 P P P OIL CD2-12 2030730 1850 1850 P P P GINJ CD2-13 2022030 155 100 98 P P P OIL CD2-14 2011770 155 100 99 P P P OIL CD2-15 2011590 1850 1850 P P P GINJ CD2-18 2031510 1850 1846 P P P GINJ CD2-19 2021120 155 100 96 P P P OIL CD2-20 2031050 155 100 98 P P P OIL CD2-21 2042450 155 100 99 P P P OIL CD2-22 2020920 1850 1867 P P P GINJ CD2-23 2021340 155 100 96 P P P OIL CD2-24 2010950 155 100 97 P P P OIL CD2-25 2020740 155 100 96 P P P OIL CD2-26 2012320 1850 1850 P P P GINJ CD2-27 2031770 1850 1840 P P P GINJ CD2-28 2022170 155 100 99 P P P OIL CD2-31 2040820 157 100 97 P P P OIL CD2-32 2020290 1850 1855 P 4 P 09/05/09 GINJ CD2-33B 2011250 155 100 96 P P P OIL CD2-34 2011910 155 100 99 P P P OIL CD2-37 2022110 155 100 96 P P P OIL CD2-39 2011600 155 100 97 P P 9 Retest Pass 9-14-09 CP OIL CD2-41 2021260 157 100 98 P P P OIL CD2-42 2010670 157 100 97 P P P OIL CD2-43 2031970 157 100 98 P P P OIL CD2-44 2021650 1850 1850 P P P GINJ CD2-45 2012120 157 100 97 P P P OIL CD2-46 2020820 1850 1860 P P P GINJ CD2-463 2081070 155 100 100 P P P OIL CD2-464 2080820 155 100 100 P P P OIL CD2-465 2081450 155 100 100 P P P OIL CD2-468 2081800 155 100 100 P P P OIL CD2-469 2081220 155 100 100 P P P OIL CD2-47 2012050 157 100 98 P P P OIL CD2-470 2081290 155 100 98 P P P OIL CD2-50 2020490 157 100 97 P P P OIL CD2-52 2030930 157 100 97 P P P OIL CD2-53 2040890 157 100 99 P P P OIL CD2-58 2030850 157 100 98 P P P OIL CD2-59 2042480 1850 1850 P P P GINJ CD2-72 2070570 155 100 98 P P P OIL CD2-74 2081970 155 100 96 P P P OIL CD2-75 2080640 155 100 95 P P P OIL Wells:49 147 Failure 3 2.04% Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ConocoPhillip Submitted By: Rich Ligenza Operator Rep: Mike MishlerField/Unit/Pad: Alpine / CRU / CD2 Remarks:9/3/09 Bob Noble said he would not be able to witness this pad and to proceed. AOGCC Rep: Waived Separator psi: Well Data Pilots Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 65 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 12/27/2009LPS 155HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD2-15 2011590 1850 1850 P P PGINJCD2-29 2021480 1850 1853 P P PGINJCD2-51 2022490 1850 1848 P P PGINJCD2-57 2040720 1850 1852 P P PGINJCD2-74 2081970 157 100 100 P P POILCD2-78 2090660 155 100 100 P P POILWells:618Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: Tim SmithField/Unit/Pad: Alpine/ CRU / CD2 MISCAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich Ligenza90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 66 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 1/9/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-107 2061890 150 100 100 P P POILWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: AlexanderField/Unit/Pad: Alpine / CRU / CD3 MISCSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 67 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 1/9/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-108 2050330WAGCD3-109 2050590 150 100 100 P P POILCD3-110 2050410 1850 1840 P P PGINJCD3-111 2060300 150 100 94 P P 9OILCD3-112 2060320 1850 1850 P P PGINJCD3-113 2070040 150 100 95 P P 9OILCD3-114 2070330WAGCD3-118 2080250 150 100 100 P P 9OILCD3-301 2070230SICD3-302 2060100SICD3-303 2080130 150 100 100 P P POILCD3-316A 2080110WAGWells:721Failure314.29%Safety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: AlexanderField/Unit/Pad: Alpine / CRU / CD3Remarks:AOGCC Rep: Lou Gamaldi Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 68 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 01/13/09LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-111 2060300 150 100 NT NT POILCD3-113 2070040 150 100 NT NT POILWells:22Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: AlexanderField/Unit/Pad: Alpine / CRU / CD3 RETESTAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 69 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 01/18/09LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-118 2080250 150NT NT NT01/18/09 OILWells:00Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-118 was shut in on 01/18/09AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: AlexanderField/Unit/Pad: Alpine / CRU / CD3 RETESTAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 70 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/5/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-107 2061890 157 100 100 P P POILCD3-109 2050590 157 100 95 P P POILCD3-111 2060300 157 100 97 P P POILCD3-113 2070040 157 100 97 P P POILCD3-114 2070330 1850 1847 P P 9GINJCD3-115 2090060 157 100 100 P P POILCD3-303 2080130 157 100 100 P P 904/06/09 OILCD3-305 2081930 157 100 100 P P POILWells:824Failure28.33%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3Operator Rep: J.DoanRemarks:CD3-303 SSSV was serviced and passed retest on 04/06/09AOGCC Rep: Waived Separator psi:Well DataPilotsCD3-114 SSSV is on Well work listOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 71 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/20/2009LPS 154HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-114 2070330 1850 NT NT P04/20/09 GINJWells:11Failure0Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3 RETESTOperator Rep: J.DoanRemarks:CD3-114 Serviced, retested, passed 4/20/09AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 72 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/24/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-108 2050330 3900 1850 1870 P P 9GINJCD3-117 2090260 157 100 97 P P POILCD3-316A 2080110 3900 1850 1820 P 4 P04/24/09 GINJWells:39Failure2CD3-108 SSSV on wire line list to repairOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-316 Serviced and retested SSV passed 4-24-09AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3 MISCOperator Rep: S. Weller90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 73 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/10/2009LPS 154HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-304 2090280 154 100 100 P P POILWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-304 is a new producing well.AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD3 MISCOperator Rep: Mike Mishler90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 74 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 5/11/2009LPSHPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-108 2050330 1850 NT NT P05/11/09 GASWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-108 Wireline replaced SSSV. Failed SVS test on 4/25/09.AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaAlpine/ CRU / CD3 MISCOperator Rep: Mike Mishler90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 75 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 7/12/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-113 2070040 150 100 103 P P POILWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-113 SSSV serviced, tested, passed 7/12/09AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3 RETESTOperator Rep: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 76 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 7/20/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-111 2060300 150 100 100 P P POILCD3-114 2070330 1850 1815 P P PGINJWells:26Failure00.00%CD3-114 SSSV serviced, tested, passed 7/20/09Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:CD3-111 SSSV serviced, tested, passed 7/20/09AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3 RETESTOperator Rep: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 77 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 10/18/2009LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-107 2061890 150 100 101 P P POILCD3-108 2050330 1850 1850 P P PGINJCD3-109 2050590 150 100 98 P P POILCD3-111 2060300 150 100 98 P P POILCD3-112 2060320 1850 1848 P P PGINJCD3-113 2070040 150 100 101 P P 9OILCD3-114 2070330 1850 1848 P P 9GINJCD3-115 2090060 150 100 100 P P POILCD3-117 2090260 150 100 50 1 43 POILCD3-301 207023006/03/08 SICD3-302 206010005/14/09 SICD3-303 2080130 150 100 99 P P POILCD3-304 2090280 150 100 95 P P POILCD3-316A 2080110 1850 1850 P P 9GINJWells:1236Failure513.89%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3Operator Rep: J.DoanRemarks:CD3-117 SSV control line was found in the blocked positionAOGCC Rep: Bob Nobel Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 78 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 10/25/2009LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-113 2070040 150 100 101P10/25/09 OILCD3-114 2070330 1850 1848P10/25/09 GINJCD3-117 2090260 150 100 100 P10/25/09 OILCD3-316A 2080110 1850 1850P10/25/09 GINJWells:44Failure00.00%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3 RETESTOperator Rep: P. MizeRemarks:CD3-113 wire line flush and brush, Retested AOGCC Rep: none Separator psi:Well DataPilotsCD3-114 Diesel flush and retestedCD3-117 changed out PIT retestedCD3-316 pulled and ran new A1 inj valve retestedOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 79 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 12/31/2009LPS 158HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-118 2080250 1850 1850 P P 8GINJCD3-316A 2080110 1850 1850 P P 8GINJWells:26Failure2Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Jody DoanField/Unit/Pad: Alpine/ CRU / CD3 MISCRemarks:CD3-118 SSSV scheduled for serviceAOGCC Rep: Waived Separator psi:Well DataPilotsCD3-316A SSSV scheduled for serviceOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 80 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 7/5/2009LPSHPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-110 2050410 3900 1850 1850 P P PGINJWells:13Failure00.00%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3Operator Rep: AlexanderRemarks:Bob Nobles was on site while CD3-110 was being converted to MI Inj. State test was AOGCC Rep: Waived Separator psi:Well DataPilotscompleted after Bob Noble left the pad.Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 81 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 7/5/2009LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD3-107 2061890 150 100 100 P P POILCD3-108 2050330 3900 1850 1810 P P PGINJCD3-109 2050590 150 100 97 P P POILCD3-111 2060300 150 100 100 P P 9OILCD3-112 2060320 3900 1850 1843 P P PGINJCD3-113 2070040 150 100 103 P P 9OILCD3-114 2070330 3900 1850 1815 P P 9GINJCD3-115 2090060 150 100 98 P P POILCD3-301 207023006/03/08 SICD3-302 206010005/14/09 SICD3-303 2080130 150 100 100 P P POILCD3-304 2061890 150 100 97 P P POILWells:1030Failure310.00%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD3Operator Rep: AlexanderRemarks:CD3-110 was in the middle of a WAG conversion to MI inj. See second sheetAOGCC Rep: Bob Noble Separator psi:Well DataPilotsState man was not at CD3 when WAG was complete so he did not witness the test.Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 82 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 1/11/2009LPS 150HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-322 2071010 1850 1840 P P PGINJWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:Lou with AOGCC was here for the CD3 testing and waved the Misc pad testing AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: BrueggemanField/Unit/Pad: Alpine / CRU / CD4 MISCAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Alexander90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 83 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/4/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-05 2071550 157 100 93 P P POILCD4-07 2071180 157 100 90 P P POILCD4-16 2061310 157 100 99 P P POILCD4-209 206065004/24/07 SICD4-210 206077011/12/08 SICD4-211 2061530 157 100 101 P P POILCD4-214 206145004/07/08 SICD4-215 2061570 157 100 96 P P 9OILCD4-301B 2071800 157 100 98 P P 9OILCD4-302 2070560 1850 1840 P P PGINJCD4-304 2071320 157 100 101 P P POILCD4-318A 2061130 157 100 97 P P POILCD4-319 2051480 1850 1845 P P PGINJCD4-320 2060550 157 100 92 P P POILWells:1133Failure26.06%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4Operator Rep: P.MizeRemarks:CD4-215 & 301 SSSV have been put on the well work list to fixAOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 84 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/15/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-215 2061570 100 NT NT POILWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4 MISCOperator Rep: P.Mize90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 85 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/15/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-215 2061570 100 NT NT POILWells:11Failure0Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4 RETESTOperator Rep: P.MizeRemarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 86 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 4/17/2009LPS 157HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-301B 2071800 100 NT NT POILWells:11Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4 RETESTOperator Rep: P.Mize90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 87 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 08/23/09LPS 154HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-321 2061420 1850 1840 P P PGINJWells:13Failure0Chuck Sheeve waived the State witnessAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderOperator Rep: MishlerField/Unit/Pad: Alpine/ CRU / CD4 MISCRemarks:AOGCC Rep: none Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 88 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 09/07/09LPS 155HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-210 2060770 155 100 100 P P POILCD4-322 2071010 1850 1845 P P PGINJWells:26Failure0Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich LigenzaOperator Rep: Noe GonzalezField/Unit/Pad: Alpine / CRU / CD4 MISCRemarks:9/03/09 Bob Noble said he would not be able to witness these tests.AOGCC Rep: Waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 89 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 10/19/2009LPS 145HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-05 2071550 145 100 100 P P POILCD4-07 2071180 145 100 96 P P POILCD4-16 2061310 145 100 94 P P POILCD4-17 206118009/09/09 SICD4-210 206077010/12/09 SICD4-211 2061530NT NT NTOILCD4-214 206145004/07/08 SICD4-215 2061570 145 100 100 P P 910/19/09 OILCD4-301B 2071800 145 100 100 P P 910/31/09 OILCD4-302 2070560 1850 1820 P P PGINJCD4-304 2071320 145 100 98 P P POILCD4-318A 2061130 145 100 100 P P POILCD4-320 2060550 145 100 100 P P POILCD4-322 2071010 1850 1825 3 P PGINJWells:1030Failure310.00%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4Operator Rep: AndrusRemarks:CD4-07, 16, 301B, 302, 318A, 320, 322 tested on 10/17/09. CD4-215 wire line flusAOGCC Rep: Bob Noble Separator psi:Well DataPilotsand brush-retested passed 10/19/09. CD4-322 inj tubing pressure 3955 psi.CD4-211 NT due to operations to normalize well, will be tested as miscellaneous.CD4-301B Brushed and flushed, tested passed 10/31/09. Submitted retest report.Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 90 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 10/31/2009LPS 145HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-301B 2071800 230 100 100 P P P10/31/09 OILWells:13Failure00.00%Field/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4 RETESTOperator Rep: D. DigulimioRemarks:CD4-301B wireline flush and brush. Retest passed 10/31/09AOGCC Rep: waived Separator psi:Well DataPilotsOil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 91 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field Date: 11/3/2009LPS 150HPS 3900SSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-211 2061530 150 100 100 P P POILWells:13Failure0 Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks: AOGCC Rep: Waived Separator psi:Well DataPilotsField/Unit/Pad:Alaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: AlexanderAlpine/ CRU / CD4 MISCOperator Rep: Digulimio90 Day 90 Day 90 Day 90 Day 90 Day ConocoPhillips 92 2009 Reservoir Surveillance Report and Reservoir March 31, 2010 Review Reports, Colville River Field ConocoPhillips 93 Date: 12/29/2009LPS 162HPSSSVSSSVRetest/SI Date Well TypeWell Permit Separ Set L/P Test Test Test Date Passed RetestNumber Number PSI PSI Trip Code Code Code Or Date Shut InCD4-321 2061420 1850 1850 P P PGINJWells:13Failure0Oil, WAG, GINJ, GAS, CYCLE, SIComponents:Failure Rate:Remarks:AOGCC Rep: Waived Separator psi:Well DataPilotsOperator Rep: Mike GravesField/Unit/Pad: Alpine/ CRU / CD4 MISCAlaska Oil and Gas Conservation CommissionSafety Valve System Test ReportOperator: ConocoPhillipSubmitted By: Rich Ligenza90 Day 90 Day 90 Day 90 Day 90 Day