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Home My WebLink AboutAIO 024 A ) ) Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ,~1' 0 O!), Lj A Order File Identifier Organizing (done) o Two-sided 1111111111111111111 þescan Needed 1111111111111111111 RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: BY: Helen ~ o Logs of variou. s k. inds: a .f:) / (. (J\-ta\'EI\LJ.s ,,~_. ~Other:: ,Mf1-p .~ t..t:..Pjl!þA.') Date 'f d. ~ os- Isl M, Date:~:}'5 ~~III~~~IIII~jLJ I NOTES: Project Proofing BY: Helen é Maria ) Scanning Preparation x 30 = + = TOTAL PAGES G'" 3 (Coun¡ ?o~s not include cover sheet) ;'\AP Date:1. dS OS /s/ I II I 1111111111111111111 BY: Helen (Maria') Production Scanning Stage 1 Page Count from Scanned File: 1 LJ-. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: t/ YES J I Helen ~ Date:'f f)..!; O!> . , YES NO NO IfJ I/I;t .p BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I111I1I1I111111111 ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1I11111111111111111 8/24/2004 Orders File Cover Page.doc r: 1) January 12, 2005 2) Febuary 12, 2005 3) February 25, 2005 4) April 19, 2005 5) April 19, 2005 6) June 20, 2007 7) November 20, 2007 INDEX AIO 24A BOREALIS BPXA's request for a modification of AIO 24 Notice of Hearing, Publication, affidavit from newspaper, copy of bulk mailing list , e-mailing list BPXA revised exhibits E-mail BPXA release of confidential provision Exhibits IV-1 and IV-2 (confidential exhibits located in Confidential Room) BPXA Request hydro testing for the PBU 207 Pipeline Replacement Project BPXA's request to continue water injection operations (AI024A-002) Area Injection Order 24A ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BPXA ) Area Injection Order 24A EXPLORATION (ALASKA) INC. ) Prudhoe Bay Field, Borealis Oil Pool for an order allowing underground ) injection of fluids for enhanced oil ) April 22, 2005 recovery in Borealis Oil Pool, Prudhoe Bay Field, North Slope, Alaska IT APPEARING THAT: 1. In correspondence dated January 12, 2005 BPXA requested the Commission to modify Area Injection Order No. 24 to allow injection of miscible hydrocarbons and Prince Creek Formation water to enhance oil recovery from the Borealis Oil Pool. 2. The Commission published notice of opportunity for public hearing for the revision of Area Injection Order No. 24 in the Anchorage Daily News on February 8, 2005. 3. On February 25, 2005 BPXA, in response to a Commission request, provided additional information and revisions to some exhibits in the January 12, 2005 correspondence. 4. The Commission received no protests to BPXA's application for modification of Area Injection Order No. 24 and no requests for public hearing. FINDINGS: 1. Project Area and Pool Description: a. Proposed Injection Area: BPXA requested authorization to inject fluids for the purpose of enhanced recovery operations in the affected area of CO 471, which defines pool rules for the Borealis Oil Pool ("BOP"), Prudhoe Bay Field, North Slope Alaska. b. Borealis Oil Pool: The BOP is defined as the accumulations of hydrocarbons common to and correlating with the interval between 6534' and 6952' measured depth ("MD") in the West Kuparuk State 1 well. AIO 24A April 22, 2005 ) ') Page 2 2. Operators/Surface Owners: BPXA provided all operators and surface owners within one-quarter mile of the BOP with a copy of the application for injection. Those operators are: BPXA, operator of Milne Point Unit and Prudhoe Bay Unit, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit. The State of Alaska, Department of Natural Resources is the only affected surface owner. 3. Description of Operation: a. Proposed MI Expansion: BPXA is requesting Commission approval to allow expansion of miscible gas injection operations throughout the BOP. Existing pilot injection is currently allowed in wells L-I05i, L-I08i and V-IOOi. The project involves the cyclical injection of water alternating with injection of enriched hydrocarbon gas ("WAG") into the oil column of the Kuparuk River Formation of the BOP. The miscible gas injection ("MI") to be used in the project will be comprised of hydrocarbon gas, enriched with intermediate hydrocarbons, principally ethane and propane. Borealis injection wells are drilled from existing L, V and Z-Pads and may be converted to allow WAG injection. Additional injectors may be drilled from these pads and potentially from a future I-Pad currently under evaluation. The Borealis MI injection project includes an MI pipeline from the existing Z-Pad and trunk and lateral distribution systems at each pad. The only surface modifications required to implement the Borealis EOR project will be to the header riser spools. A request was made May 28, 2004 to convert wells L-I05i, L-I08i and V-I OOi to implement an EOR MI injection pilot program. The Commission approved pilot operations for a three-month period and the wells were converted to MI injection on June 29, 2004. Subsequent approvals have extended the project to the current time. Well L-I 08i, due to a well tie-in timing issue, was not used in the Pilot. The main objectives of the pilot were to evaluate available MI system injection pressure and reservoir gas injectivity. Injectivity was confirmed as sufficient to handle the rates needed to provide both voidage replacement and EOR sweep in an effective manner. b. Proposed Prince Creek Water Injection: BPXA is requesting approval to allow injection of Prince Creek source water as needed for pressure support. Currently, produced water is being supplied from existing infrastructure to support the BOP waterflood. Evaluation continues for use of Prince Creek (Ugnu and Sagavanirktok) as supply for future waterflood. The W -400 well startup October 15, 2004 proves Prince Creek deliverability of at least 20,000 BWPD. The Borealis Owners intend to inject water at a voidage replacement ratio greater than one to restore reservoir pressure. The additional Prince Creek source water will be helpful to meet this goal. 4. Current Development at Borealis: Drilling commenced July 2001 with production startup in November 2001. Water AIO 24A April 22, 2005 ) ) Page 3 injection started in June 2002. Borealis production is commingled on the surface with IP A and Orion production on L, V, and Z-Pads and processed at GC-2. Listed below is additional information describing the BOP as of December 1, 2004. More detail can be found in BPXA' s application. · 17 wells drilled at V-Pad - 10 oil producers- 4 water injectors - 1 WAG injectors - 2 abandoned for sidetrack · 23 wells drilled at L-Pad - 14 oil producers - 8 water injectors - 1 WAG inj ector · 2 wells drilled at Z-Pad - 1 oil producer - 1 well shut-in · Oil Production Rate: 21,300 BOPD · Gas Production Rate: 17,000 MSCFD · Water Production Rate: 18,000 MBWPD · Water Injection Rate: 55,300 BWPD · MI Injection Rate: 0 MMSCFD · Cumulative Oil Production: 30.3 MMSTBO · Cumulative Gas Production: 26.4 MMSCF · Cumulative Water Production: 9.5 MMSTB · Cumulative Water Injection: 33.5 MMSTB · Cumulative Gas Injection: 0.6 BCF BPXA is currently evaluating a proposed expansion of the Z- Pad, which would accommodate additional development of the southern expansion area. Additionally, BPXA is considering development of the northwest portion of the BOP from a proposed I-Pad location. 5. Geoloe:ic Information: a. Available Data: Production, seismic and well data have been used to characterize the BOP. b. Stratigraphy: The affected reservoir is the early Cretaceous-aged Kuparuk River Formation ("Kuparuk"), which consists of very fine to medium grained quartz- rich sandstone, interbedded with siltstone and mudstone. Within the BOP, BPXA divides the Kuparuk into four stratigraphic intervals that are designated, from oldest to youngest, A, B, C and D. The C interval contains the primary reservoir sands of the BOP, and secondary accumulations occur in the A and B sands. c. Structure Overview: Within the BOP, the top of the Kuparuk lies between 6,200 and 6,900 feet true vertical depth subsea ("TVD"). The structure of interest is a northwest-to-southeast trending antiform that is broken by two sets of faults: an older set of northwest-southeast trending faults and a younger set of north-south striking faults. The complexity of faulting, and production data from the BOP demonstrate the reservoir is divided into separate fault bounded compartments. ) ) AIO 24A April 22, 2005 Page 4 d. Trapping Mechanism: Hydrocarbons are structurally and stratigraphically trapped within the Borealis Oil Pool. The oil accumulation is bounded to the southwest by northwest and north-south trending faults and the oil/water contact ("OWC"). To the northeast, the accumulation is limited by the down-dip intersection of the top of the reservoir with the OWC and with a series of north-south trending faults. To the southeast, the reservoir is truncated by an intra-formational unconformity and onlap onto the Prudhoe high. To the northeast, the reservoir sand intervals degrade to non-reservoir quality. e. Confining Intervals: The impermeable shales of the Kalubik Formation and the HRZ have a combined thickness of approximately 110 feet and provide upper confinement for the Kuparuk reservoir sands within the BOP. Lower confinement is provided by shale and siltstone of the Miluveach and Kingak Formations. 6. Well L02S: The logs of existing injection wells are on file with the Commission. 7. Mechanical Inte2rity: All wells drilled and converted for injection service have been completed in accordance with 20 AAC 25.412, thus satisfying the mechanical integrity requirements as required by 20 AAC 25.402. The casing program for planned conversions of existing water injection wells was permitted and completed in accordance with 20 AAC 25.030. A state witnessed MIT is required on wells prior to injection startup. In drilling all Borealis injection wells, the casing is pressure tested in accordance with 20 AAC 25.030. Injection well tubing/casing annulus pressures will be monitored and recorded on a regular basis. The Borealis Oil Pool injection wells will be designed to comply with the requirements specified in 20 AAC 25.412. 8. Iniection Fluids: Type of Fluid/Source: BPXA is requesting authorization to inject the following fluids in the Borealis Oil Pool within the Prudhoe Bay Field: · Produced water from Borealis or Prudhoe Bay Unit production facilities for the purposes of pressure maintenance and enhanced recovery; · Miscible Injectant from the Prudhoe Bay Central Gas Facility. · Source water from the Prince Creek Formation; · Non-hazardous water collected from well house cellars and standing ponds; · Source water from a Seawater Treatment Plant. 9. Iniectant Composition and Compatibility with Formation: As previously approved by the Commission, produced water from GC-2 is used as the primary water source for Borealis injection. Injection performance, core, log and pressure-buildup analyses indicate no significant problems with clay swelling or AIO 24A April 22, 2005 ) Page 5 compatibility with in-situ fluids. BPXA analysis of cores from the BOP wells indicates relatively low clay content. Petrographic analysis indicates that clay volumes in the better quality sand sections (>20 md) are in the range of 3 - 6%. Clay volumes increase to approximately 6 - 12% in rock with permeabilities in the range of 10 - 20 md. Below 10 md, clay volumes increase to a range of 12 - 200/0. Most of the identified clay is present as intergranular matrix, having been intermixed with the sand through burrowing. The overall clay composition is a mixture of roughly equal amounts of kaolinite, illite and mixed layer illite/smectite. No chlorite was reported during petrographic analysis. The presence of iron-bearing minerals suggests that the use of strong acids should be avoided in breakdown treatments, spacers, etc. Water from the seawater treatment plant has been successfully used for injection within the Kuparuk of the Pt. McIntyre Oil Pool. Geochemical modeling indicates that a combination of GC-2 produced water and connate water is likely to form calcium carbonate and barium sulfate scale in the production welis and downstream production equipment. Scale precipitation will be controlled using scale inhibition methods similar to those used at Kuparuk River Unit and Milne Point Unit. Miscible gas is a hydrocarbon with similar composition to reservoir fluids in the BOP therefore no compatibility issues are anticipated with the formation or confining zones. The composition of injection water from the Prince Creek aquifer is expected to fall within the range of Well W -400 and MPF -02 produced water compositions, less than 10,000-ppm total dissolved solids. Milne Point Unit F -Pad Prince Creek source water has been injected since 1996 into the Milne Point Kuparuk Reservoir, lithologically similar to the BOP, with no apparent formation damage. A single well chemical tracer test in BOP well L-122 conducted using 640 barrels of Prince Creek Source water did not detect any formation damage. 10. Injection Volumes and Pressures: Maximum expected water injection rates are 90 MBWPD, with maximum surface and bottom hole pressures of 3000 psi and 5000 psi, respectively. Maximum expected MI rates are 70 MMSCFD, with maximum surface pressures of 3800 psi. 11. Fracture Information: The L-l 0 1 well was fracture stimulated in the BOP Kuparuk C sand at the Borealis Oil Pool, with a formation breakdown pressure of 4290 psi, which calculates to a fracture gradient of 0.65 psi/ft at initial reservoir conditions. This data agrees with data from offset fields containing wells completed in the Kuparuk. The Kalubik and HRZ shales overlie the Kuparuk at the Borealis Pool with a combined thickness of approximately 110 feet. The HRZ is a thick shale sequence, which tends to behave as a plastic medium and can be expected to contain AlO 24A April 22, 2005 ') ) Page 6 significantly higher pressures than sandstones of the Kuparuk. Mechanical properties determined from log and core data for the HRZ and Kalubik intervals indicate a fracture gradient from approximately 0.8 to 0.9 psi/ft. Dipole Sonic evaluations of these strata have measured values equal to or greater than 0.99 psi/ft confining stress. The Kuparuk is underlain by the MiluveachlKingak shale sequence. A leakoff test in the Kingak shale formation demonstrated leakoff at a gradient of approximately 0.85 psi/ft. The expected maximum injection pressure in the Borealis wells will not initiate or propagate fractures through the confining strata, and, therefore, will not allow injection or formation fluid to enter any freshwater strata. There is no evidence of injection out of zone for similar Kuparuk waterflood operations on the North Slope. Water injection operations at the Borealis Pool are expected to be above the Kuparuk parting pressure to enhance injectivity and improve recovery of oil. Fracture propagation models confirm that injection above the parting pressure will not exceed the integrity of the confining zone. 12. Aquifer Exemption: On July 11, 1986, the Commission approved Aquifer Exemption Order 1 ("AEO-l ") for Class II injection activities within the Western Operating Area of the Prudhoe Bay Unit. The Borealis Pool is entirely within the area covered by AEO-l. 13. Hvdrocarbon Recovery: a. Primary and Waterflood Recovery: Estimates for original oil in place ("OOIP") for the BOP reflect current well control, stratigraphic and structural interpretation, and rock and fluid properties. The BOP current estimate of OOIP ranges between 310 and 430 MMSTB. The extent of the range of estimates is due primarily to uncertainty in the BOP structural definition, oil water contact and reservoir net pay interval estimates. There is no free gas cap known in Borealis. Estimated associated formation gas in place ranges from 135 to 200 BSCF. Primary and waterflood oil recovery is estimated at 100-130 MMSTB based on field performance reservoir modeling. A three-dimensional geologic and dynamic flow model of the Borealis accumulation has been constructed based on detailed stratigraphic and structural interpretation. This model provides the bulk reservoir volume and porosity distribution for the BOP. The model area encompasses the known extent of the Borealis accumulation. Model results indicate recovery of 27-30% OOIP from primary and waterflood recovery mechanisms. b. Miscible Injection Enhanced Oil Recovery It is estimated that implementation of the proposed MI project will increase recovery by 5% to 8%, or approximately 18-25 MMSTB of oil for the project. Reservoir simulation based projections indicate the project will increase total recovery from the BOP to 35% OOIP. AIO 24A April 22, 2005 ) ) Page 7 A completed slim-tube experiment defines the minimum miscibility enrichment (MME) of the MI and confirms miscibility of BOP oil with the proposed MI over the expected range of reservoir pressures. The MI source is the miscible gas from the Prudhoe Oil Pool, which is richer than is required for Borealis miscibility. The experiments have been matched using a Kuparuk 12-component equation of state. BOP minimum miscibility pressure ("MMP") with the injectant is 2150 psi as determined with the equation of state and consistent with the slim-tube experiments. BOP average reservoir pressure is 3004 psi at the datum of 6600' tvdss; this is the average of pressures measured in twelve wells in August of 2004. These data are in agreement with the simulation field model estimate of 3098 psi within the BOP area boundary. Pressure measurements in a few producers are very close or slightly below the MMP; however, all pattern area pressures are above the MMP. Project performance forecasting is based on fine-scale fully compositional reservoir simulation using Well L-1 0 1 fluid properties and whole core reservoir description. The initial MI slug size target is approximately 7% of a type injection-producer pattern polygon hydrocarbon pore volume with a nominal WAG ratio of 1.0. The cumulative target size is nominally 20% of pattern hydrocarbon pore volume or 95+ BSCF of miscible gas injection for the BOP, though MI injection parameters will be subject to adjustment as field conditions and performance indicate. After the cumulative target slug size of MI has been injected into the formation, pressure support will be maintained with water injection. The BOP EaR gross efficiency is roughly 5 MSCF MI per barrel of EaR oil generated. Without the BOP EaR Project injection, this MI would have been injected into mature IP A EaR patterns that have a gross efficiency of 26 MSCF/STB. The Kuparuk River Oil Pool EaR project, a close analog for the proposed BOP EaR project, commenced in 1988 and has incremental EaR recovery of approximately 8-12% over waterflood. Analysis of Borealis oil samples indicates similarity to Kuparuk oil characteristics for bulk composition, wettability, and relative permeability effects. c. Surveillance Plan; To ensure the efficient allocation of MI for the Borealis EaR project, rate and pressure response to injection will be monitored. Production fluid compositional samples will be taken at least annually to assess pattern efficiency based on the returned MI (RMI) ratio. Offset producers of injectors currently on MI can be sampled on a more frequent basis to help determine break through times and flood efficiency. Water injection surveillance will continue using pressure falloffs and other monitoring methods as required by patterns. Injection of water and miscible gas into patterns will be evaluated on a regular basis to address pattern performance and optimum injection rates to maximize recovery. AlO 24A April 22, 2005 ) ) Page 8 14. Mechanical Condition of Wells within a One-quarter Mile Radius of Injectors A report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well has been filed with the AOGCC and is a part of the record for this order. Mechanical integrity has been established for the subject wells based on calculated cement tops being at an adequate height above the injection zone to prevent fluid that is injected into the BOP from flowing into other zones or to the surface. Static pressure and repeat formation tester data support the conclusion that the completions in offset wells beyond this radius are sufficient to contain high pressure fluids, including gas, within the BOP. Prior to any enhanced injection on wells without prior certification, wells will be demonstrated through established approved testing procedures, with a requested State Inspector present, to confirm mechanical integrity as required by 20 AAC 25 .402 (e). Although injection pressure will exceed average BOP reservoir pressure, reservoir modeling indicates rapid reservoir pressure falloff away from the injector during water and MI injection. Reservoir modeling indicates a radius of pressure influence less than 1000 feet from the injector at the end of the MI cycle. Well tests are conducted routinely to monitor the flow rates from wells for purposes of reservoir management, production diagnostics and field allocation. CONCLUSIONS: 1. The application requirements of 20 AAC 25.402 have been met. 2. An area injection order is appropriate to allow injection of water, miscible gas, and tracer fluids within the Borealis Oil Pool as described in BPXA's January 12, 2005 application under 20 AAC 25.460. 3. Information provided in this application shows that water and miscible gas injection will significantly improve recovery. 4. The annual surveillance report required by CO 471 will keep the Commission apprised of the performance of the injection project and EaR process evaluation. 5. Injection of enhanced recovery fluids at pressures above fracture gradient may be necessary in order to provide sufficient pressure support. The fracture gradient of the Borealis Oil Pool is significantly below the recorded leakoff pressures of confining shale intervals and as such the water will preferentially stay within zone. 6. Injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the wellbore and appropriate operating conditions. 7. Reservoir surveillance, operating parameter surveillance and mechanical integrity tests will demonstrate appropriate performance of the enhanced oil recovery proj ect or disclose possible abnormalities. AlO 24A April 22, 2005 ') ) Page 9 8. The Borealis Oil Pool injection wells are designed to comply with the mechanical integrity requirements specified in 20 AAC 25.412. 9. BP intends to replace voidage within the BOP and reservoir pressures will be maintained above the minimum miscibility pressure. 10. The record for this order includes the hearing records and administrative files related to Area Injection Order No. 24, including administrative approvals issued under that order NOW, THEREFORE, IT IS ORDERED: 1. This order supersedes Area Injection Order No. 24 dated May 29,2002. 2. The underground injection of fluids pursuant to the project described in BPXA's application dated January 12, 2005 is permitted in the following area, subject to the conditions, limitations, and requirements established in the rules set out below and statewide requirements under 20 AAC 25 (to the extent not superseded by these rules or the Borealis Oil Pool rules). Umiat Meridian TI2N-RI0E: TI2N-RI1E: TIIN-RIIE: TIIN-RI2E: TI2N-RI2E: ADL 25637 Sec 13,24 ADL 47447 Sec 16 (SW/4 and W/2 NW/4 and W/2 SE/4), 21, 22 SW/4 and W/2 NW/4 and S/2 SE/4 ADL 47446 Sec 17, 18, 19, 20 ADL 28238 Sec 26 S/2 and W/2 NW/4 and SE/4 NW/4, 35, 36 ADL 28239 Sec 27, 28, 33, 34 ADL 47449 Sec 29, 30, 32 ADL 28240 Sec 1,2,11,12 ADL28241 Sec3,4,9, 10 ADL 28245 Sec 13, 14, 24 ADL 28244 Sec 15 ADL 28246 See 25 ADL 28261 See 9 W /2 ADL 47450 Sec 5 S/2, 6 S/2 and NW/4 and W/2 NE/4, 7, 8 ADL 28263 See 16 W/2, 21 W/2 ADL 28262 See 17, 18, 19, 20 ADL 47452 See 28 W/2, 33 W/2 ADL 47453 See 29, 30, 31, 32 ADL 28259 See 31 W /2 and W /2 SE/4 AIO 24A April 22, 2005 ) ) Page 10 Rule 1 Authorized Iniection Strata for Enhanced Recovery Injection of authorized fluids for purposes of pressure maintenance and enhanced recovery is permitted into strata that are common to, and correlate with, the interval between 6534' and 6952' MD in the West Kuparuk State #1 well in the Prudhoe Bay Field. Rule 2 Authorized In.iection Fluids Fluids authorized for injection within the affected area are: a. produced water from Borealis Oil Pool or Prudhoe Bay Unit production facilities for the purposes of pressure maintenance and enhanced recovery; b. non-hazardous water collected from Borealis well house cellars and standing ponds; c. tracer survey fluid to monitor reservoir performance d. source water from a seawater treatment plant; e. enriched hydrocarbon gas from the Prudhoe Bay Unit processing facilities, with the condition that the average Borealis Oil Pool reservoir pressure must be maintained above the minimum miscibility of the injectant; and f. source water from the Prince Creek Formation. Rule 3 Fluid Injection Wells The underground injection of fluids must be through a well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280 and 20 AAC 25.412. The application to drill or convert a well for injection must be accompanied by sufficient information to verify the mechanical condition of wells within one-quarter mile radius. The information must include cementing records, cement quality log or formation integrity test records. Rule 4 Monitoring the Tubing-Casing Annulus Pressure Variations The tubing-casing annulus pressure and injection rate of each injection well must be checked at least weekly to confirm continued mechanical integrity. Rule 5 Demonstration of Tubing-Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures that the tubing-casing annulus for each injection well is pressure tested prior to initiating injection, following well workovers affecting mechanical integrity, and at least once every four years thereafter. AIO 24A April 22, 2005 ) ) Page 11 Rule 6 Notification of Improper Class II Iniection Injection of fluids other than those listed in Rule 2 without prior authorization is considered improper Class II injection. Upon discovery of such an event, the operator must immediately notify the Commission, provide details of the operation, and propose actions to prevent recurrence. Additionally, notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 7 Other conditions a. It is a condition of this authorization that the operator complies with all applicable Commission regulations. b. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Rule 8 Administrative Action Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. ,':J~:'~/;;~~-;Tt '-_.~ .I') t:;:' -.:~.... ,;',' ".~',.....~l\t-ò .l;:';. :~./>'\~'~ \ \\ I I'·~~''· C> ~~. ..,.;'/" "\ :," \ I / / I"~;' {;:. '\ (:'/ ';. ':"" " . ~ ( ,"'... .,,-,,'1' !/ ¡( ~,.'-.: ,"~. "<-S;,:~_.~:·~·~~:~:d~ \\ I, ., . " \. "'"., ~-"':,..~ I ,", ~'. . ,r ¡, " ~. ,/, . '" ~ II r "\ I I ,. ~ .., . ...·":;¡~:~W Daniel T. Seamount, Jr., Commissioner ....;:.~0~jj;~'/ Alaska Oil and Gas Conservation Commission AS 31.05.080 p'r~~ìdës't1ìát;¡thin 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., loth day after the application for rehearing was filed), Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Rìverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 ) Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ) David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Hou~on,TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 mcJ/ ;6 cL¿J .cc ' I/~ 7.;t)-Ó j \.10 24A ) ) Subject: AlO 24A From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Fri, 22 Apr 2005 08:24:15 -0800 ~:~::t1~êis~1~se1~r~dpi~nts:;I ........... ..........!; '....... ..... .."'. ....'>T '<.1. ..... .... ........... .... .T.> BC~; ,.Rob~~ EMintz <ro bert _ mintz@law~~tate.:~~us<,G.ru:istil1e.Hans~l1., <c.h~nsen@iogcp.~tate;ok.us>,·.·.T~rri~,Wub~1~i~h~p,blet1@hp~P0LÐ>'.·. $ondra:Ste~m~ <Ste'YnutSD@?BP.çom~,..S.cott&Car~l1ny .TaY!Qr<~taylor@al~sl~~~pet(,stan~kj·...<stanekj·@Ul1?cal.com>, ecolflW ~¢CQla~($tnl~~~es.org>-f rOl~~ra~s4ale.,~rp~er~~~d~1~~gci~~e~~ "Jrrnjr'l..<tr111jrl@ªol.com>, jbrid(He<jbriddl~@11iarGtthonoÜ:co111>,sþªn7g'ks~aIleg~~y~rg~Te~g~s.!qot;l1>,jdarÍing~0n <jdaxlingt()n@forestoil.cQ11)c,né}son<1¢els9~@petrpl~µmne~S;Rom~~.cbøddy .......... .' :..,...'., . ...., <cÞ9d?y~~siÞ~U~.c~rp~, ·MarkDal~?n!<,11ar~.dal'tp~@~?ril)ç.ç~m>"'ISl1~ol).D?~ellx <~11~µnon...40rn~llX~c01'J.8COphiHipsi:çÅm~t ".'N1~~<',f·;\ypp~e~~~t""¡::,',;..·':... '..,.... .........'....... ",.. .".... ..... 1....' ~Í11~~~ B1~Br~~st~r@)ç9ßdçg1?þpÙW~.cR111~.,'Bpþ','~?qþ'($i~letk~~per~orgf,\Vdv.· <wdy~dnr ;;state.ak.Üs>, tj·~,·.ftj,r~d~~...st~~e.·.fLk;llS~.~..· b brit~~.. <c~.~r!tcp~~J~~.~.~:.~~~.~..···~jnrls9Ji··'r~j ntl~?p~.~vrY'~1JgtEtz..~~m>, Çfi¥I~S,Q'1Dqnnyn,l?c4ar1;~ê·.o'4Q~~H@"V~q9¡1CPµ1?,·",g.ai1dY'ErS'~UI~rA",'·~S¡~ill~~@J3r~C9l11(>' ......, I" ',: "¡. ',,' , !'~,,'I;' ',': ;,:':' ';:1:';' ~":,,;:,,, '!':'" I, I, ,','i,;::' '''Iill Y" ,'I, ":",:'1,, "';: ''''::' :;' ,':;:' "':"1",,, ",': ,!I",::!" ,,'Ii'·, :¡'\, I,:", ".,', ~", ,I:, :"" ,:'1 ,"II' ,I,,;' "',"', ",.,1 ,<.,' '''Debor~li J .!Jqne~'" ..<JönesÐQ@BP:poW?>;''P~utC!.!l)r~ttr'!.<h,~ªttR9@ß?çprn»'ir'S~~\r.ep·.~... Rdssberg" 4.R9.s~Þ,eB.~@~1)·90W> ,~LQi~' <lQ~s@i?leltkF~F~f .or~~, 'I?ap~~{)s~4fkU~cne~s~~U~Ci()rgf,; q9rdQn PPsp~sil...-<;~o~pisG~aJ.CRœ~,.···¡'FFaµSJsi:S:.S:9tpW:yr",~Sqril11epFS;~~m,·?9111~~...N1t~yt"êc~u!tz . <¥i~el~~.c~ll1t~@BP.CQll1> ~'.. u~~9k'..V;I.:'!;º~~v'~r":,~~'1~f~~~0Y@,~r·~o~>,;: "º~!,J: KJeppil1" <I<leplliq~~a;p .com>, "IJanet.q!:iJ?I'ª~t";'·.~PI~tt~l)I@)BP ;co~:>",l'R?s~~f,M,.[ac9ij~en" .' <J acobsRM@BE . QQl1}::>, 'dqº~el «(i&()l)k~I@~t1~14~~Om>;;"l11(;KªY <mçkªy@gq;i.~et>,Barbår&· F Fullmer :, "::, ' ,," " I,::,'" ~ "'~ ': ':"" ' " :', '/', :'~"ql,l,', /':':/:",,',' '", I:!' :'I'!:,'~'<' ::::. :' " ' <'"",, ,:' "':,1' ,'I"" ." >, I, "', ,I,': : '!~ :' ,I, ,,' ',I, """"":' :,'" ':' ,I ", ','!:,.- "1'1 !', ;':''', ,> I, " , ":" I,~:I : '~',I '\:'-' .::< ,,' ,:::" i ,': I , "" I <b~b~~.f.{unT~f@conocophiqips~'ç01117?:,;b?pa~~wf<bþcasÍ'rf@bp.çon1>~ICh~les ..Barker, <;þ~lqjr@~~~s':goy:>',..· dpµg~sçhul~~e~40~g~~çÞ~1~z~@~tPYP~~gY::,?º~~>W~ÂlfQrq. I <h~~.alford;~e~x~np1()bil.çol11> ,MarkIÇovab,'>)1esnol@g9i.ntt>,gsHfoff. ...... .... . <gspfoff@aurQrapower;com>, Greg&Nady?gre~g.nadY@sh~ILç?tn~,.Fre~iSteece . . .' <fred. steeee@state.sd. us» ,~cr()tty;<rcrotty@ch2tl1.. com)., j yj oD,~s<j ej one~@aurorapo"Wer . com>, dapa <dapa@alaska.net>,jroderick ~jrodefick@gcLµ~t>,eyancy<eYancy@seal.-tite.net> ,.il J ames·M. Ruud" <j ames.'m.ruud@conocophillips.com>,Brit Lively<mapalaska@ak.net>, j ah <j ah@dnr~state.ak. us>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <bµonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, 10ren_Ieman <loren_Ieman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz.<jwkatz@sso.org>, Suzan J·Hill <suzan_hill@dec.state.ak.us>, tablerk <tablerk@unoca1.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobi1.com>, marty <marty@rkindustria1.com>, ghammons <ghammons@ao1.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANClER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoi1.com>, Garry Catron <catrongr@bp.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoi1.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP .com>, Steve Lambe <larnbes@unoca1.com>, jack newell <j ack.newell@acsalaska.net>, James Scherr 1 of2 4/22/2005 8:24 AM \1024A ) ) <~ arneS.Scherr~nl1ps.gov>,·d~vid rbbY<DaVi4.R9bý@1111~s.goy>,.Til11,EawIor <Til11-:.J-.awlqf@aJ<. bIm.gov>, L)'pnª~Kahp <Lynl1qa.:.Kahl1@f~s.g()v>,J erry,DethIefs <JerrY;C..De~hIefs@c.olfOCophillips.cQrn>,. JerrY:De~hlefs <Fn16.17@conocophillips;com>, crockett@~Qg~tor~~ ':r~l}1er~She;field~sl1effiyIq~~og(l.?r~~, Jon9qlt~ '. ..' ........ ......' ..' <J on.Goltz@c9nosophinips.'com>,...Ro~er',B~1~~·<Ff9g~r.b¡~lmaJ1~cpriocQphillips.cqm>·,Mindy Lewis <rnlewis@brrnala.w.com>,·.·H'arry, L~þert<~ap)' :1(l]Dpert(@h?neywell;com>,.Kari.MorifUiY <moriarty@~oga.?rg:>,g~ttrAlf?Io <palfaiq@Yal10ö.èorp.("Cyrit~ia~,Mciver <bren__mciver@a(hllin;state.a~.us» I I' ;,::1 " ::!> , 20f2 4/22/2005 8:24 AM . . SARAH PALIN, GOVERNOR AI.A~1iA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. AIO 3.018 ADMINISTRATIVE APPROVAL NO. AIO 4E.023 ADMINISTRATIVE APPROVAL NO. AIO 20.001 ADMINISTRATIVE APPROVAL NO. AIO 24A.00l ADMINISTRATIVE APPRO V AL NO. AIO 25A.00l ADMINISTRA TIVE APPROVAL NO. AIO 26A.00l Ms. Colleen Burgh Waste Technical Authority BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Request for Administrative Approval to Inject Hydrotest Water Prudhoe Bay Unit Oil Pools Dear Ms. Burgh: BP Exploration (Alaska), Inc. ("BPXA") has notified the Commission of ongoing and planned construction of replacement oil transit pipeline segments throughout the Prudhoe Bay Unit fields. The pipeline segments must undergo pressure testing (referred to as "hydrotesting") to verify integrity. Filtered lake water that is chemically treated with a corrosion inhibitor and an oxygen scavenger will be used for hydrotesting the pipeline segments. The Commission has previously approved the injection of filtered and treated lake water used to hydrotest a pipeline segment between Lisburne L 1 production pad and the Lisburne Production Center ("LPC"), part of the Greater Point McIntyre development area. Administrative approval under Area Injection Order ("Ala") 4E authorized, as an enhanced recovery injection fluid, hydro test water consisting of treated and filtered lake water stored for fire fighting purposes (refer to Ala 4E.22). The Commission approves BPXA's June 20, 2007 written request for authorization to inject hydrotest water as an enhanced recovery fluid. The composition of hydrotest water referred to in BPXA's current request appears to be no different than that used to test the Lisburne replacement pipeline segment. BPXA has demonstrated to the satisfaction of the Commission that the hydro test water, as described in the June 20, 2007 œquest, is consistent and compatible with fluids used in routine enhanced recovery operations in the Prudhoe Bay Unit oil pools and will not adversely impact the reservoir or production equipment. EaR Injection of HYdrot~Vater June 2 L 2007 Page 2 0 f 2 . The following AIO rules governing Injection operations in Prudhoe Bay Unit oil pools are amended to include filtered and chemically treated lake water used for hydro testing replacement pipeline segments to the list of fluids authorized for enhanced oil recovery injection: AI 0 3 (Prudhoe Oil Pool), Rule 1 Ala 4E (Prudhoe Oil Pool), Rule 1 AIO 20 (Midnight Sun Oil Pool), Rule 1 AI 0 24A (Borealis Oil Pool), Rule 2 Ala 25A (Polaris Oil Pool), Rule 3 Ala 26A (Orion Oil Pool), Rule 3 Any change in the composition of the hydrotest water that has the potential to affect its compatibility with formation fluid or the normal enhanced recovery injection fluid will require additional review by the Commission before injection occurs. Similarly, any change in treating chemical use that results in the hydrotest fluid exhibiting hazardous characteristics will require additional review. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorae, Alaska and dated June 21, 2007. ¿ Cathy . Foerster Comm ssioner ì . Mary Jones XTO Energy Inc Cartography 810 Houston Street. Ste 2000 Ft Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, 10 83702 Baker Oil Tools 4730 Business Park Blvd" #44 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 David McCaleb IHS Energy Group GEPS 5333 Westhelmer, Ste 100 Houston. TX 77056 . Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Mona Dickens Tesoro Refining and Marketing Co Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Halliburton 6900 Arctic Blvd, Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 - I I)ublic '\¡otlce Lone Creek q and Admm c\PP.I'S Pßl . Subject: Public Notice Lone Creek #4 and A.dmin Approval's PBl; From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Thu, 21 Jun 2007 14:55:49 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, trmjrl <trmjrl@aol.com>, jdarlington <jdarlington@forestoi1.com>, nelson <knelson@petroleumnews.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, Dave Roby <daveJoby@admin.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnel1@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mike1.Schu1tz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f. fullmer@conocophillips.com>, doug_schultze <doug_ schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobi1.com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shel1.com>, Fred Steece <fred. steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, j ejones <j ej ones@aurorapower.com>, dapa <dapa@alaska.net>, eyancy <eyancy@sea1-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <bl@mapalaska.com>,jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@a1askadc.org>, tablerk <tab1erk@unoca1.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobi1.com>, marty <marty@rkindustria1.com>, ghammons <ghammons@ao1.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <ifbmg@uaa.a1aska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <todd.durkee@anadarko.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoi1.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoi1.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, James Scherr <james.scherr@mms.gov>, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda _ Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffie1d@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Gary Rogers <gary _rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copou10s@dnr.state.ak.us>, Ken <klyons@otsint1.com>, Steve Lambert <salambert@unoca1.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bin Walker <biil-wwa@ak.net>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough <admin@a1eutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <cammy_taylor@dnr.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, of2 6/2\ /20072:56 PM Public :\otice Lone Creek F-+ and Admin APP'" PBt· . Keith Wiles <kwiles@marathonoil.com>, Deanna Gamble <dgamble@kakivik.com>, James B Regg <j im _regg@admin.state.ak.us>, Catherine P Foerster <cathy _ foerster@admin.state.ak.us>, gregory micallef <micallef@clearwire.net>, Laura Silliphant <laura _ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobil.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve_moothart@dnr.state.ak.us>, Anna Raff <anna.raf:fi§dowjones.com>, Cliff Posey <cliff@posey.org>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson <temple_davidson@dnr.state.ak.us>, Walter Featherly <WFeatherly@PattonBoggs.com>, Tricia Waggoner <twaggoner@nrginc.com>, John Spain <jps@stateside.com>, Cody Rice <Cody _Rice@legis.state.ak.us>, John Garing <garingJD@bp.com>, Harry Engel <engelhr@bp.com>, Jim Winegarner <jimwinegamer@brooksrangepetro.com>, Matt Rader <mattJader@dnr.state.ak.us>, carol smyth <carol.smyth@shell.com>, Arthur C Saltmarsh <art _ saltmarsh@admin.state.ak.us>, Chris Gay <cdgay@marathonoil.com>, foms@mtaonline.net, Rudy Brueggeman <rudy.brueggemann@international.gc.ca>, Cary Carrigan <cary@kfqd.com>, Sonja Frankllin <sfranklin6@bloomberg.net>, Mike Bill <Michael.Bill@bp.com>, Walter Quay <WQuay@chevron.com>, "Alan Birnbaum <\"\"Alan J Birnbaum \">" <alan_ bimbaum \"@law.state.ak.us>, Randall Kanady <Randall.B.Kanady@conocophillips.com>, MJ Loveland <N1878@conocophillips.com>, Christian Gou-Leonhardt <Christian _ Gou- Leonhardt@legis.state.ak.us> Jody Colombie <jodv colombieCa;admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/pdf various admin approvals AIO.pdf Content-Encoding: base64 Content-Type: application/pdf Lone Creek Content-Encoding: base64 20f2 6/21/20072:56 PM ,~ i"~ ' ~~~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ SARAH PALIN, GOVERNOR ~7~T~~r ~-7~[~ ~~ L~i``D`~7[~~ST 333 W 7th AVENUE, SUITE 100 CDis-7E~QA-~~j` C~r~II-7''-7''I~l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 24A.002 Mr. Steve Rossberg Wells Program Manager Attention: Well Integrity Coordinator, PRB-20 BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU V-114A (PTD 2031850) Request for Administrative Approval Borealis Oil Pool Dear Mr. Rossberg: In accordance with Rule 8 of Area Injection Order ("AIO") 24A.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants the request of BP Exploration (Alaska) Inc. ("BPXA") for administrative approval to continue water injection in the subject well. Before listing the approval conditions, however, the Commission will comment on BPXA's operation of this well with pressure communication in violation of Commission requirements. Borealis Oil Pool (part of the Prudhoe Bay Unit) well V-114A commenced enriched gas injection in September 2006. Pressure data indicate the well operated with a stable inner annulus pressure ranging from 600 to 900 psi until mid-June 2007. During subsequent months leading up to BPXA's notification to the Commission on August 29, 2007 of pressure communication, PBU V-pad personnel engaged in the active management of increasing inner annulus pressure with periodic bleeds. Pad operating personnel monitoring the well pressures have applied annulus pressure triggers from Conservation Order 492 (applicable to production wells only) in operating this well. BPXA is reminded that there is a more stringent requirement governing annular pressures in injection wells than development wells; immediate notification is required for a~ indication of pressure communication or leakage in an injection well. Pressure data provided with this administrative approval request indicate that the Commission should have been notified of pressure communication, and the well should have been swapped to water injection in June 2007 instead of September 2007. At no time during the months of increasing inner annulus pressure has there been any indication of pressure communication or leakage outside of the well; all injection has remained confined to the Borealis Oil Pool and the wellbore. Therefore, the Commission does not intend to take enforcement action against BPXA at this time for the continued injection of gas into PBU V- 114A in the presence of pressure communication to the inner annulus. Notification delays in the future will result in enforcement actions. AIO 24A.002 December 10, 2007 Page 2 of 2 .~, Regarding the administrative approval request to allow continued injection of water only, the Commission finds that BPXA has elected to perform no corrective action at this time on PBU V- 114A. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures and wellhead pressure trend plots, PBU V-114A exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU V-114A is conditioned upon the following: 1. BPXA shall daily record wellhead pressures, injection rate, and annuli pressure bleeds; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and IA pressure bleeds; 3. Every 2 years, BPXA shall perform an MIT-IA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After a well shut in due to a change in the well's mechanical condition, injection in the well shall not be restarted without AOGCC approval, and 6. The MIT anniversary date is November 3, 2007. As provided in AS 31.05.080(a}, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. DONE at c i rage, Alaska and dated December 10, 2007. oh K. Orman Daniel T. amount, Jr. Cathy P Foerster Chairman Commissioner Commissioner ~.~. Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Tuesday, December 11, 2007 1:09 PM Subject: aio24a-002 PBU V-114A Attachments: aio24a-002.pdf BCC:McIver, C (DOA); 'Alan Birnbaum <""Alan J Birnbaum "> (alan.birnbaum@aiaska.gov)'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur C Saltmarsh'; 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'carol smyth'; 'Cary Carrigan'; 'Catherine P Foerster'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David L Boelens'; 'David Steingreaber ; 'ddonkel'; 'Deanna Gamble'; 'Deborah J. Jones'; 'doug_schultze ; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons ; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James B Regg'; 'James M. Ruud'; 'James Scherr'; 'Janet D. Platt'; 'jdarlington'; 'jejones'; 'Jerry McCutcheon'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=Crockett@aoga.org'; 'mail=fours@mtaonline.net'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'marty'r 'Matt Rader'; 'mckay'; 'Meghan Poweli'; 'Mike Bi11'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson ; 'mkm7200'; 'Nick W. Glover'; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern ; `rcrotty ;Rice, Cody J (DNR}; 'rmclean ; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly ; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'stanekj'; 'Stephen F Davies'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble ; 'Thomas E Maunder'; 'Tim Lawlor'; 'Todd Durkee'; 'trmjrl ; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachm ents: aio24a-002.pdf; 12/11/2007 Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Michael Parks Mark Wedman 200 North 3rd Street, #1202 Marple's Business Newsletter Halliburton Boise, ID 83702 117 West Mercer St, Ste 200 6900 Arctic Blvd. Seattle, WA 98119-3960 Anchorage, AK 99502 Baker Oil Tools Schlumberger Ciri 4730 Business Park Blvd., #44 Drilling and Measurements Land Department Anchorage, AK 99503 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Richard Wagner Refuge Manager 399 West Riverview Avenue PO Box 60868 PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Soldotna, AK 99669-2139 Cliff Burglin Bernie Karl North Slope Borough PO Box 70131 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99707 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 / ~ ~` ~ ~~ ~Z/~ ~ 7 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 November 20, 2007 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 by Subject: Prudhoe Bay well V-114A (PTD #2031850) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay well V-114A. Well V-114A exhibits manageable inner annulus re-pressurization of 120 psi/day when on MI injeciton. However, a pressure test of the inner annulus passed to 4000 psi, indicating the tubing and production casing are competent. Based upon sound .engineering practice, two barriers have been established and the well can be safely operated. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well V-114A is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Andrea Hughes at 659-5102. Sincerely, Steve Rossberg Wells Program Manager A~';~ ~f~~ka iii u~~ ~~r;. ~~~srtis~~~4 ~n~fr~r~~~ • Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby/Olsen Dube/Hughes West Area Manager Ray Oakley Harry Engel Janice Vosika • • Prudhoe Bay Oil Pool well V-114A Technical Justification for Administrative Approval Request November 20, 2007 Well History and Status Prudhoe Bay well V-114A (PTD #2031850) exhibits manageable inner annulus repressurization indicated by wellhead pressure trends on a TIO plot. An MIT-IA to 4000 psi passed on 11/03/07 indicating competent tubing and production casing. Recent Well Events: > 09/04/07: IA BUR 120 psi /day on MI > 10/02/07: MITIA Passed to 1500 psi > 11/03/07: AOGCC MITIA Passed to 4000 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 4000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 2-year MIT-IA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut-in and the AOGCC notified if there is any change in the wells mechanical condition. 4,00 • Tbg 3,000 2, 000 1,000 • ~~ ~r ~- ~~ 4SP • ~~ •• t t • ~ _ ~ •- ^ _ ~ ^^ ~ ~ ^ ^ • ~ 1 ~ ^ ~ ~ ^ ^ OA MAASP ^~ ^ N~ _ ~~ ~ ^ ^ ~~ ~ ~_ ^~' d ^ __. ^ IA • OA OOA ^ OOOA 0 ~ -- - - 11 /25/2006 1 /24/2007 3/26/2007 5/26/2007 7/26/2007 9/25/2007 11 /25/2007 TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = N/A KB. ELEV - 81.8' BF. ELEV...- _ 55.9' KOP = 300' Max Angle = 94 @ 11396' Datum MD = 8151' Datum TVD = 6600' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" ~--I 2946' Minimum ID = 3.813" @ 2212' HES X NIPPLE ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" (-I 8025' TOP OF 7" BAKER WHIPSTOCK f-) $221' 9-5/8" HES EZSV H $239' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I PERFORATVON SUMMARY REF LOG: ANGLE AT TOP PERF: @ 9630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 9630 - 9680 O 10/17/04 2-1/2" 6 9800 - 9920 O 10/17/04 2-1/2" 4 11100 - 11335 O 11/20/03 V -114A S NOTES: 2212' ~-~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2852 2684 30 KBG-2 DMY BK 0 03/13!04 5 3654 3311 32 KBG-2 DMY BK 0 11/30/03 4 4732 4208 33 KBG-2 DMY BK 0 03!13/04 3 5807 5041 32 KBG-2 DMY BK 0 03!13/04 2 6509 5702 36 KBG-2 DMY BK 0 03/13/04 1 7150 6196 51 KBG-2 DMY BK 0 03/13/04 7948 4-1/2" HES X NIP, ID = 3.813"~ 7ggg' 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 7992' 4-1/2" HES X NIP, ID = 3.813" $013' 4-1/2" HES X NIP, ID = 3.813" 8021 ~ 5" X 7" BAKER HMC LNR HGR 8025 4-1/2" WLEG, ID = 4.000" 3041' --i5" X 4-1/2" XO, ID = 3.950" 7"WINDOW 8221' - 8233' g2$$' PUP JT W/ RA TAG 9793' PUP JT W/ RA TAG _ 10340' -rPUP JT W/ RA TAG PBTD -1 11345, ~- 4-1/2" SOLID LNR, 12.6 #, L-80, ID = 3.958" 11432' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/22!03 JDM/TLP INITIAL COMPLETION 11/30/03 JLJ/TLP GLV CIO 03/24/04 JLJ/TLH GLV C/O 10/17/04 DBMiTLP 4-1/2" TBG, ADD PERFS BOREALIS UNff WELL: V-114A PERMIT No: 2031850 API No: 50-029-23178-01 SEC 11, T11 N, R11 E, 4049' NSL & 1789' WEL BP Exploration (Alaska) 0 0 0 0 0 0 v ~ T a o 3 0 m nj LL V o O 0 N o O O 0 ~ 0 a o ~~ ~ °o 0 v 0 0 0 N 0 11/25 V-114 Daily Allocated Injection Plot • o N o o V "' N I n V,.r C f-, ,- °o = J ~ N ~ N ~Q ~ J 0 0 0 X2006 1/25/2007 3/25/2007 5/25/2007 7/25/2007 9/25/2007 11/25/2007 WHIP swl PW I+DW MGI GAS '~6 . . June 20,2007 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Hydrotest Water: PBU 2007 Pipeline Replacement Project Administrative Approval Request: Prudhoe Oil Pool, Area Injection Orders 3 and 4E Midnight sun Oil Pool, Area Injection Order 20 Borealis Oil Pool, Area Injection Order 24A Polaris Oil Pool, Area Injection Order 25A Orion Oil Pool, Area Injection Order 26A '.).'.' Dear Mr. Norman: BP Exploration (Alaska) Inc. (BPXA) requests approval under Area Injection Order (AIO) 4E Rule 9, AIO 3 Rule 9, AIO 20 Rule 9, Ala 24A Rule 8, AIO 25A Rule 13, and Ala 26A, Rule 11 to utilize water from pressure testing (also known as hydrotesting) replacement oil transit pipeline segments as an enhanced oil recovery (EOR) fluid in the various Greater Prudhoe Bay pools listed above. This water will temporarily augment ongoing water injection in the pool by providing additional water volume. During injection, the Class IT disposal wells at FS-3 and GC-l will be shut in to ensure all of the hydrotest water will be utilized for EOR. FS-l to Skid 50 Oil Transit Line Segment Approximately 26,500 feet of 18" pipeline is under construction to replace a section of oil transit pipeline. This line will carry production from the FS-l to Skid 50 and is scheduled for pressure testing before the end of June. Approximately 7700 barrels of treated lake water will be used to pressure test the line. After the pressure test is complete, the hydrotest water will be displaced into a tank and then into pipeline to FS-3, mixing with produced fluids. At FS-3 the water will be separated in the process trains and injected in EOR wells at DS 13 and 14. In this way, the hydrotest water will augment the current water injection in the Prudhoe Oil Pool. The total volume of produced water injection is about 150,000 bpd, and the dilution of the hydrotest water with produced water will minimize any potential water compatibility issues. GC-2 to GC-l Oil Transit Line Segment Apprüximately 16,200 feet of 20" pipeline is under construction to replace a seciÍon of oil transit pipeline. This line will carry production from GC-2 to GC-l and is scheduled for pressure testing in late June or early July. Approximately 5900 barrels of treated lake Mr. John Norman, chelan June 20. 2007 Page 2 . water will be used to pressure test the line. After the pressure test is complete, the hydrotest water will be displaced into a tank and then into pipeline near GC-1, mixing with produced fluids. Depending on the process configuration at the time, the GC-1 water may also be routed to GC-3 then to FS-3. Given the configuration uncertainty, some hydrotest water could be injected in the following pools: Prudhoe, Midnight Sun, Borealis, Polaris, or Orion, at pads E, L, R, U, V, W, Z or DS 13 and 14. In this way, the hydrotest water will augment the current water injection. The total volume of produced water at GC-1 is about 100,000 bpd and the dilution of the hydrotest water with produced water will minimize any potential water compatibility issues In both cases, the lake water will be filtered and treated with a corrosion inhibitor and an oxygen scavenger. At the specified chemical concentrations, the treated lake water will be considered non-hazardous. Alternatives to proposed beneficial use of the hydrotest water include surface discharge after filtration under a NPDES permit, or trucking the water to a suitable disposal site. The difficulty in removing very small particles limits the effectiveness of filtration treatment to meet NPDES effluent limits for turbidity and color. The option of trucking the hydrotest water to Pad 3 would require multiple loads increasing the complexity of the job and the possibility of a spill. We believe the best option for handling the hydrotest water from this replacement pipeline is to use it to augment the OPB waterflood/EOR project. Additional pipeline replacement projects are in progress or are planned elsewhere in the Greater Prudhoe Bay area, so BPXA may have additional requests to beneficially reuse pipeline hydrotest water at other field locations in the future. Please call me at 564-5229 if you have any questions. Sincerely, . / /J Il/!., y~ , I'd ~{~ liYUð'L- Colleen Burgh' Waste Technical Authority cc: James Regg, AOGCC #5 bp ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 April 19, 2005 Commissioners Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: Borealis Pool Area Injection Order 24 Modification Release of Confidentiality Provision - Exhibits IV -1 and IV-2 Dear Commissioners: I am writing to amend my January 12, 2005 letter requesting modification of Borealis Pool Area Injection Order 24. In that letter, I requested that Exhibits IV -1 and IV -2 be kept confidential by the Commission under AS 31.05.035. This letter was then updated on January 28,2005 to include revisions to Exhibits IV-l and IV-2. Please consider this letter as authorization from BP Exploration (Alaska) Inc. to amend these prior letters to release the Commission from our confidentiality request for Exhibits IV-l and IV-2, as amended. Should you have any questions, please contact Claire Sullivan at 564-5841. Thank you. Sincerely, /~~ Gil Beuhler GPB WEST Manager Cc: Sonny Rix, EM Dan Kruse, CP AI Leonard Gurule, Forest Steve Wright, Chevron Claire Sullivan, BPXA Gary Gustafson, BPXA Leslie Senden, BPXA Jane Williamson, AOGCC Mike Kotowski, DNR #4 RE: Borealis Pool Rules Area, Confidentiality, and pilot term ') ) Subject: RE: Borealis Pool Rules Area, Confidentiality, and pilot tenn From: "Sullivan, Claire" <sullivc 1 @bp.com> Date: Tue, 19 Apr 2005 13:29:11 -0800 To:· Jane. Williamson <jane_\villiamson@admin.state.ak.us>, "Smith, Bruce W" <SmithBW@bp.com>, "Gustafson, Gary G (Alaska)" <GustafGG@bp.com> CC: Robert P Crandall <bob _crandall@admin.state.ak.us> Jane The previous email dated Jan 27 2005 does state our position. I have since found the official letters that had been sent to your office via certified mail, dated 1/28/05 and 2/25/05, and unfortunately the letter does not specifically release you from the confidentiality of exhibits IV-1 and IV-2. I will request the Gus write a new letter specifically addressing this. In summary, the maps labeled exhibits IV-1 and IV-2 are not confidential, however the SWTT must remain confidential. Claire From: Jane Williamson [mailto:jane_williamson@admin.state.ak.us] Sent: Tuesday, April 19, 2005 12:02 PM To: Sullivan, Claire; Smith, Bruce W Cc: Robert P Crandall Subject: Re: Borealis Pool Rules Area, Confidentiality, and pilot term Claire, Bruce, Maybe this e-mail was it? You did send out revised information on Feb. 25 and a letter request for extending the pilot. However, neither one specifically removed the confidentiality requirement (though requirement for confidentiality of the single well tracer test was emphasized.) Based upon your e-mail, though, I would assume this e-mail is your official response and we can put these items in the public record. Correct? One other item. Bruce, you brought over some infonnation for Bob on Prince Creek use in Milne. Is that for the public record? Jane Sullivan, Claire wrote: Jane Here is my initial response. Still looking for the letter that went out at this time. Claire From: Sullivan, Claire Sent: Thursday, January 27, 2005 3:35 PM To: Ijane williamson@admín.state.ak.us' Cc: Paskvan, Frank A; Landmesser, Chip (ASRC ENERGY SERVICES); Smith, Bruce W; Cerveny, Phillip F; Carhart, Steve R; Beuhler, GiI G 10f3 4/19/2005 1 :33 PM RE: Borealis Pool Rules Area, Confidentiality, and pilot term ') ) Subject: Borealis Pool Rules Area, Confidentiality, and pilot term Jane Thanks for your input on our application. We have addressed all your issues and a revised application will go in the mail tomorrow. 1) The boundaries on this map reflect pre-PA expansion boundaries. They have been changed to reflect the larger, single PA boundary. 2) We agree with you and have removed the confidentiality request on exhibits IV-1 and IV-2. 3) A letter requesting an extension was sent out this week. 4) Done Thanks again, Claire Sullivan Geophysicist and Area Lead for Aurora-Borealis and EWE Prudhoe Bay West BPXA 564-5841 -----Origi nal Message----- . From: Mary Williamson rmailto:jane williamson(á2admin.state.ak.us] Sent: Tuesday, January 25, 2005 12:03 PM 'To: Smith, BrUce W; Paskvan, Frank A . Cc: Beuhler, Gil G; Robert P Crandall Subject: Borealis Pool Rules Area, Confidentiality; and pilot term Bruce and Frank, 1) Exhibit 1-1 shows the pool boundary, which appears to be the same as the pool rule boundary. However IV-1 ,and IV-2 appear to have a different boundaries marked. Perhaps these are the PA and Unit boundaries? It would be helpful if the pool rule boundary is marked on these. 2) We don't understand why Exhibits IV-1 and IV-2 are requested to be held confidential. Net pore foot maps were provided in the original pool rules hearings, and these were not requested to be held confidential. Plus, Gil Buehler requested in his letter of April 16, 2002 that the term requested for confidentiality of three of the exhibits was 24 months, so all those exhibits are in the public domain as well. We request that you reconsider your request for confidential treatment of Exhibits IV-1 and IV-2 (with the pool boundaries), else provide more thorough information as to why confidential treatment is needed. 3) The term on the MI pilot ends Jan 31. We suggest you apply for an extension of the pilot to April 1. This should allow sufficient time to process the full AIO. 4) Finally, we likely will amend the Conservation Order - CO 471, to specifically allow MI as an enhanced recovery technique at the time the AIO is amended to allow MI throughout the pool. No need to change your application for this, however, you might want to mention this in your letter you 20f3 4/19/2005 1 :33 PM RE: Borealis Pool Rules Area, Confidentiality, and pilot term ) ) send back with the Exhibits. Jane 30f3 4/19/2005 1 :33 PM #3 · .bp ) ) February 25, 2005 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Commissioners Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Borealis Pool Area Injection Order 24 and Conservation Order 471 Modification - Revised Exhibits Dear Commissioners: On behalf of the Prudhoe Bay Owners, BP Exploration (Alaska) Inc. (BPXA) requests modification of Conservation Order No. 471 and Area Injection Order No. 24 to encompass the injection of miscible injectant and Prince Creek water to enhance recovery from the Borealis Oil Pool. Per Commission request, the attached information revises Exhibits VII-1 with the addition of a pressure profile; adds Exhibit IX-1 documenting the sensitivities of EOR recovery to cumulative MI target size; and adds Exhibit IX-2 showing the current pressures in Borealis field. Also per Commission request, the previously submitted single well tracer test (SWTT) documentation may be added to the hearing record for this order, but must be maintained as confidential pursuant to AS 31.05.035(d). This material is not information that is required to be submitted under AS 31.05.035(a), and contains trade secrets and engineering, geological and other information, and interpretations thereof. BPXA hereby supplements the record in response to the above matters. Should you have any questions regarding this request, please contact Bruce Smith at 564- 5093, Frank Paskvan at 564-5749. or Claire Sullivan at 564-5841. Sincerely, ..._.~<~~~ Gil Beuhler GPB WEST Manager f~~ ~:~ FEB 2 § 2005 Attachments D~~ CC: Sonny Rix (ExxonMobil) Dan Kruse (CPAI) Paul Winslow (Forest Oil) Steve Wright (Chevron) Claire Sullivan, BPXA Bruce Smith, BPXA ,/ '~ ) ) Gary Gustafson, BPXA Leslie Senden, BPXA Jane Williamson, AOGCC Mike Kotowski, DNR List of Exhibits VII-l Borealis Forecast Production, Injection and Pressure (revised) IX -1: Borealis Type Pattern Model Incremental EaR Oil Recovery IX-2: Borealis Pressure at August, 2004 35,000 30,000 ~ 25,000 -B ~ 20,000 15,000 10,000 5,000 £ ro ~ Õ Exhibit VII-l (REVISED): Borealis Forecast Production, Injection and Pressure Inclusive of Water and Miscible Gas Injection Projects ---------- Oil Production Jan-04 Jan-09 Jan-14 Jan-19 Jan-24 Jan-29 Year ---------- Gas -+- MI Injection, m;cfþd J ___ Production, Imcfþd --- GOR, sc£'stb 60000 . 50000 ~' u 40000 eI.) g £ 30000 . ro ~ eI.) 20000 ro 0 ]0000 0 Jan-04 Jan-09 o -- J - ;g- el.) 4::: ~- 1000 ~ 0::: o o = = . . ~ . ~ . . ... 500 Jan-14 Jan-19 Jan-24 Jan-29 Year - --~. --------- .' Water 90,000 80,000 - ~ 70,000 ::ö 60,000 - 6 £ 50,000 - ..-- ro ~ 40,000 - 1-0 £ 30,000 ro ~ 20,000 - ----.- Injection, bwipd 1 0,000 ~ ___ Production, bwpd J an-04 Jan-09 Jan-14 Jan-19 J an- 24 Jan-29 Year Oil Recovery, Field Pressme 40% 35% - ~ 30% - Q 25% - 11) 8 20% ~ 11) ~ 15%- Õ 10%- 5% - 0% Jan-Ol 3700; 3500 - 3300: = . ~ '-" -- 3100 - RecoveryTo Date ___ Recovery Forecast --- Field Model Pressme -- 2900 -- 2700' 2500 Jan-06 Jan-ll Jan-16 Jan-21 Jan-26 Year ... r::: Q) u ~ Q) D. ~ Q¡ 0.1 > o u Q) a: o Exhibit IX-I: Borealis Type Pattern Model Incremental EOR Oil Recovery 0.2 -~----- o o 0.1 Borealis Type Pattern 2D Model Recovery Model does not account for areal sweep efficiency "-'. -. . -' ""':¡ "-. :. - 0.2 0.3 0.4 0.5 0.6 Miscible Gas Injection Slug Size, % HPV ------------ .".:,; - .- -", _4....... - .'. - ~ ,- - . . . ".-". -···-._r· . . -------------- --- - -----------". . . I . ¡__~ T~~~~c~_~~.ry~ . . .-"- 0.7 '. . -. _:.- "1- _ .;" , . '. :. .- .-' c_ 0.8 .. "i. '-" ~ 0.9 #2 STATE OF ALASKA ) NOTICE TO PUBLISHER ) ADVERTISING ORDER NO. ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED .COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AO-02514031 F AOGCC R 333 W 7th Ave, Ste 100 o Anchorage, AK. 99501 M AGENCY CONTACT DATE OF A.O. Jodv Colombie PHONE February 8., 2005 PCN -(907) 793 -17·?·1 DATES ADVERTISEMENT REQUIRED~ ~. . Anchorage Daily News PO Box 149001 Anchorage, AK. 99514 .February 7,2005 THE MATERIAL. BETWEEN THE DOUBLE LINES MUST BE PRINTED m.lTs . ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement X Legal 'D Display Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED REF 1 2 3 .. Sr:NDïNVÖlë~·-ïÑ"··"··"'··"···"'^> AOGCC, 333 W.1thAve., Suite 100 TRIPLìcATETO A nr.hnnu7p' A K QQA:iO 1 TYPE NUMBER AMOUNT DATE VI:N ARD 02910 TOTAL OF PAGE 1 OF ALL PAGES $ ? PAr,F~ COMMENTS I=IN 411nllNT !:.v r.r. Pr.1I Ir. 4r.r.T I=V NMR DlST UQ 05 02140100 73451 2 3 4 REQUISlo DIVISION APPROVAL: ) ) .Ñotice of'Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Borealis Area Injection Order 24 Modification BP Exploration (Alaska) Inc., by letter dated January 12, 2005, has requested that the Alaska Oil and Gas Conservation Commission modify Area Injection Order No. 24, in accordance with 20 AAC 25.460, to allow injection of miscible hydrocarbons and Prince Creek water to enhance recovery :trom the Borealis Oil Pool. The Borealis Oil Pool is located within TI2N-RI0E, TI2N-RIIE, TIIN-RI1E, TIIN-RI2E, TI2N-RI2E Umiat Median. The Commission has tentatively scheduled a public hearing on this application for March 15, 2005 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on February 25, 2005. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. In addition, a person may submit a written protest or written comments regardin~ this application to the Alaska Oil and Gas Conservation Commission at 333 West 7t Avenue, Suite 100, Anchorage, Alaska 99501. Written protest or comments must be received no later than 4:30 pm on March 11, 2005 except that if the Commission decides to hold a public hearing, written protest or comments must be received no later than the conclusion of the March 15,2005 hearing. /' Published Date: 2/8/05 ADN AO# 02514031 ) Anchorage Daily News Affidavit of Publication } 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 407985 02/08/2005 02514031 STOF0330 $141.36 $141.36 $0.00 $0.00 $0.00 $0.00 $0.00 $141.36 Notice of Public Hearing ST A TE OF ALASKA THIRD JUDICIAL DISTRICT STATE OF ALASKA Ala¿~~~~~~g~i~~a~ . Commission Re: Borealis Area Injection Order 24 Modification BP Exploration (Alaska) Inc., bY let- ter dated January 12, 2005, hås requested that the Alaska 011 and G a sC 0 n s e r vat I on Commission modifY I Area In lectlon Order No. 24, i.l1.~Gcordance with 20 A'AC 25.460, to allow Injection of mis- cible hYdrocarbons and ~~~~~~!r{:;oký:r~tf;oU:', ¡ the BorealIs Oil Pool. I The Borealis 011 Pool is located within T12N-R10E,Tl2N-Rl1 E T11N-R11E,T11N-R12E T12N-R12E Umiat Me- dian. The Commission has tentatively scheduled a public hearing on this application for March . 15,2005 at 9:00am at t hoe 0 f fie e s 0 f the A laskaO i I and Gas Conservation Commis- sion at 333 West 7th Avenue, Suite 100, An- chorage, Alaskci 99501. A personmav request that the tentatively scheduled hearing be held by filing a writ· ten request with the Commission no later than 4:30 pm on Feb- ruary 25, 2005. If a request for a hear- ing is not timelY filed, the CommissIon may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hear- ing, please call 793-1221. Teresita Peralta, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper h,lS been approved by the Third Judicial Court, Anchorage, Alaska, and it now and hé1s been published in the Erlg1ish continually as a daily newspaper in /\ nC!lof8gc,^ \C1~;kc1, ~lnd it is now and during all s8id ti.mc vv8s printed in an office maintained at the aforesaid plåce of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (tlll.dnot in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of sé1id period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed Y¡¡/~?/JoJ Subscribed and sworn to me before this date: I~ß[/wJa{j /O,()J)OS- Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska .~~;/.. ."~:27 ':.ijJjJ)) In addition, a person may submit a written protest or written comments regarding this application to the ,I, Alask.a··QiI· Q,nd Gas Conservation Commis- sion at 333 West7~h Avenue, SµitelOO, Ai1~ chorage, Alaska 99501. Written protest or commentsrnust be re- ceived no 'later than 4: 30 pm on.March 11, 2005 except that if the Commission ·decides to hold a public hearing, written protest or comments must be re- ceived no lat.erthan I the concl.usionof the March 15, i005hedriÌ1g; I I fyou .ate a~p~rso.njl with a disabill,ty ,who may needspe'Cla'lac,,1 commodations !hor. der to com¡;ne:nt or to attend the public hear- ing,p'ease contact Jody Colombie at 793-1221 no later than March 11, 2005. /s/: John K. Norman Chairman ADN AO# 02514031 Pub: February 8, 2005 02-902 (Rev. 3/94) STATE OF ALASKA ADVERTISING ORDER . .. ·~~E.~U<:)~:fP~I~\(9IÇI:~DI)~SS·.···:. Publisher/O -')al Copies: Department Fiscal, Departmf'receiving AO.FRM NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., AO 02514031 CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH - ATTACHED COPY OF > ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AGENCY CONTACT DATE OF A.O. Jodv Colomhie Febnulrv ,~ ?öoš PHONE PCN (9Ù7) 791 -11.1.1 DATES ADVERTISEMENT REQUIRED: AOGCC 333West 7th 1\vel1u~~ Suite 100 o A nr.hor~ap. A 1( QQ"n 1 M 907-793-1221 R ~ . Anchorage Daily News PO Box 149001 Anchorage, Ai{ 99514 February 8, 2005 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRlNTE:O IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INS1RUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first dUly swörn, aëëördiiig to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2005, and thereafter for _ consecutive days, the last puBliëätiön apþéaring ön thé _ day of .2005, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2005, Notary public for state of My commission expires ~orealis Notice ) ) Subject: Borealis Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Däte: Mort, 07 Feb 2005 12:04:28 -0900 Tó: undisClosed-recipients:; BeC: Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubblet1@bp.com:>, Sondra Stewman <StèwmaSD@BP.éÖfi1>, Scòtt & Cammy Taylor <štàylör@alaska,nèt>, startëkj <stanekj@urtöêal,êÖm>, ëêòlàw <ecölaw@tfustêëS,ötg>, tösëtagsdä1è <tösétagsdalë@gci,rtet>, trtrtjtl <trtnjr l@aoLcom>, jbriddle <jbriddlë@marathonoi1.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.cotn>, nelson <knelson@petroleu11U1ews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P . Worcester" <mark. p. worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah 1. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, LoÎs <loÎs@înletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, ¡¡Francis S. Sommerlt <SommerFS@BP.com>, Mikel Schultz <Mikel. Schultz@BP.com>, IINick W. Glover" <GloverNW@BP.com>, IDaryl J. Kleppin <KleppiDE@BP.com>, IiJanetD. Platt <PlattID@BP.com>, IIRosanne M. Jacobsenll <JacobsRM@BP.com>, ddonkel <ddonkel@cflrr.com>, Collins Mount <collins_mount@revenue.state.ak.us>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_ schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno l@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, FredSteece <fTed. steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>,jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james. m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, Kurt E Olson <kurt_olson@legis.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, lotèfi_leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john. s. haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@ao1.com>, rmclean <rmc1ean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Bill Miller <Bill_Miller@xtoalaska.com>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Garry Catron <catrongr@bp.com>, Shannaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin _ dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Vaughn Swartz <vaughn.swartz@rbccm.com>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <James.Scherr@mms.gov>, david roby 10f2 2/7/2005 12:16 PM Borealis Notice ) ') <David.Roby@mms.gov>, Tim Lawlor <Tim ~awlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Jerry Dethlefs <n 1617@conocophillips.com>, crockett@aoga.org, , Cynthia B Mciver <bren _ mciver@admin.state.ak.us> I Content- Type: application/msword ¡IN otice _ Borealis.doc I Content-Encoding: base64 20f2 2/7/2005 12:16 PM >ublic Notice ) ) Subject: Public Notice From: Jody .Colombie <jody _ colombie@admin.state.ak.us> Date: Mon, 07 Feb 2005 12:08:23 -0900 To: Legal Ads Anchorage Daily News <legalads@adn.com> .:. . Please publish on 2/8/05. I Content-Type: application/msword [Ad Order form.doc . Content-Encoding: base64 I I Content- Type: application/msword II· Notice _Borealis.doc Content-Encoding: base64 1 of 1 2/7/2005 12:16 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 ) Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 SC,hlLJmberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 ) David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise,lD 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 /1a/kcl' ;;/ðjtJ 5 RE: PllbHc Notice ) ) Subject: RE: Public 'Notice From: legalads <legalads@adn.com> Date: Mon, 07 Feb 2005 14:40:05 -0900 To: Jody Colombie <jody_colombie@admin.state.ak.us> Hello lody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need add itional information. Account Nwnber: STOF 0330 Legal Ad Number: 407985 Publication Date(s): February 8, 2005 Your Reference or PO#: 02514031 Cost of Legal Notice: $141.36 Additional Charges Web Linle E-Mail Link: Bolding: Total Cost to Place Legal Notice: $141.36 Your Legal Notice Will Appear On The Web: www.adn.com: XXXX Your Legal Notice Win Not Appear On The Web: www.adn.com: Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 ---------- From: Jody Colombie Sent: Monday, February 7,2005 12:08 PM To: legalads Subject: Public Notice «File: Ad Order form.doc»«File: Notice Borealis.doc» Please publish on 2/8/05. 1 of 1 2/7/2005 3:24 PM #1 . ) BP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 ) January 12, 2005 aECe1VED Commissioners Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 JAN 1 4 2005 tJr .a=.~ . T "-n RE: Borealis Pool Area Injection Order 24 Modification Dear Commissioners: On behalf of the Prudhoe Bay Owners, BP Exploration (Alaska) Inc. (BPXA) requests modification of Area Injection Order No. 24 (AIO 24) to encompass the injection of miscible injectant and Prince Creek water to enhance recovery from the Borealis Oil Pool. The attached information supplements our April 11, 2002 application for a Borealis Area Injection Order. Please hold Exhibits IV-1 and IV-2 confidential under AS 31.05.035. Should you have any questions regarding this request, please contact Bruce Smith at 564-5093 or Frank Paskvan at 564-5749. Sincerely, ~~~ GiI Beuhler GPB WEST Manager Attachments CC: Sonny Rix (ExxonMobil) Dan Kruse (CPAI) Bradley Brice (Forest Oil) Steve Wright (Chevron) Claire Sullivan, BPXA Bruce Smith, BPXA Gary Gustafson, BPXA Leslie Senden, BPXA Jane Williamson, AOGCC Mike Kotowski, DNR ) ) Application for BorealIS Area Injection Order Modification 1/12/05 Application for :Modification of '. Area Injection Order '24' ... ., .,~'. Borealis Oil Pool January 12, 2005 Area Injection Operations.................................................................................................. 2 Plat of Proj ect Area........................................................................................................ 2 Operators/Surface Owners............................................................................................. 2 Description of Operation..................................................................... ............ ............... 4 Geologic Information..... ...... .... ......... ... ...... ......... .... ...... ..... ..... ............ ........ .... ..... ... .......8 Mechanical Integrity of Inj ection Wells......................................................................... 8 Inj ection Fluids.............................................................................................................. 9 Type of Fluid/Source. ........ ...... .... ... ... ..... ...... .... .... ........ .... ...... .... ... ..... ... ..... ....... ... ..... 9 Composition and Compatibility with Formation and Confining Zones ................... 10 Maximum Inj ected Rate........................................................................................... 10 Injection Pressures....................................................................................................... 11 Fracture Information.................................................................................................... 11 Formation Water Quality....................... .................... .................................................. 12 Fresh Water Strata................................................................................................... 12 Hydrocarbon Recovery................................................................................................ 12 Surveillance Plan..................................................................................................... 15 Mechanical Condition of Wells Within a One-quarter Mile Radius of Injectors .........15 List of Exhibits................................................................................................................ 17 List of Exhibits (continued) ......... .................. .......... ......... ................. .............. ......... ....... 18 Exhibits 1 of 1 7 ) ) Application for Borea1Ís Area Injection Order Modification 1/12/05 Area Injection Operations This application, prepared in accordance with 20 AAC 25.402 (Enhanced Recovery Operations) and 20 AAC 25.460 (Area Injection Orders), requests modification of Area Injection Order No. 24, the Borealis Oil Pool (BOP) and Area Injection Order to encompass injection of Prince Creek Aquifer Water and of Miscible Injectant (MI) for enhanced recovery operations (EOR). The following information is provided to supplement the BPXA April 11, 2002 application for an Area Injection Order for the BOP, and to provide data regarding MI pilot activities initiated in 2004 under Area Injection Orders 24.001 and 24.002. Plat of Project Area 20 AAC 25.402(c)(I) Exhibit 1-1 shows the general location of the BOP and Injection Area. Exhibit 1-2 shows all existing and planned injection wells, production wells, abandoned wells, dry holes, and any other wells within the BOP as of December 1, 2004. Specific approvals for any new injection wells or existing wells to be converted to injection service will be obtained pursuant to 20 AAC 25.005, 25.280 and 25.507, or any applicable successor regulation. Exhibit 1-3 shows the GC-2 area facilities, roads and pipelines. Operators/Surface Owners 20 AAC 25.402(c)(2) and 20 AAC 25.402(c)(3) BP Exploration (Alaska) Inc. is the designated operator of the Borealis Participating Area. Surface Owners within a one-quarter mile radius of injectors within the Borealis Participating Area are as followings: State of Alaska Department of Natural Resources Division of Mining, Land & Water P.O. Box 107034 Anchorage, AK 99510 Exhibit II-I is an affidavit showing that the Operators and Surface Owners within a one- quarter mile radius of the injectors within the Borealis Participating Area have been provided a copy of this application. 2 of 1 7 Application for Borea.J Area Injection Order Modification ) 1/12/05 Description of Operation 20 AAC 25 .402( c)( 4) The development plans for the BOP are described in Section II of the BOP application, dated June 15, 2001, and are updated annually with reports to the commission. The following summarizes current field status, recent field activities/accomplishments, development drilling learnings, facility and project status, water injection, and a miscible gas injection pilot for the BOP. Field Status: BOP development has focused on phased drilling of 40 production and injection wells from L and V Pads. Drilling commenced July 2001 with production startup in November 2001. Water injection started in June 2002. Borealis production is commingled with IPA and Orion production on L, V, and Z-Pads and processed at GC-2. Tertiary recovery, utilizing IPA miscible gas for Water-Alternating-Gas injection started in V-100 and L-105 wells in June 2004. Exhibit 111-1 shows historical BOP production and injection. Listed below is additional information describing the BOP as of December 1, 2004: · 17 wells drilled at V -Pad - 10 oil producers - 4 water injectors - 1 WAG injectors · 23 wells drilled at L- Pad - 14 oil producers - 8 water injectors - 1 WAG injector · 2 wells drilled at Z-Pad - 1 oil producer - 1 well shut-in · Oil Production Rate: 21,300 BOPD · Gas Production Rate: 17,000 MSCFD · Water Production Rate: 18,000 MBWPD · Water Injection Rate: 55,300 BWPD · MI Injection Rate: 0 MMSCFD · Cumulative Oil Production: 30.3 MMSTBO · Cumulative Gas Production: 26.4 MMSCF · Cumulative Water Production: 9.5 MMSTB · Cumulative Water Injection: 33.5 MMSTB · Cumulative Gas Injection: 0.6 BCF 3 of 1 7 ) ) ) Application for Borea1ís Area Injection Order Modification 1/12/05 Summary of Activities Summarized below are significant accomplishments at Borealis from August 1, 2003 through December 1, 2004: · After a three-year drilling hiatus at Z-Pad, BPXA drilled and completed well Z- 100 under Tract Operations. A Z-Pad Kuparuk development program had been abandoned after the poor performance of Z-101 in 2001. Acquisition of the Z-39 well core in 2002, improved the Kuparuk reservoir description and understanding of siderite cementation in the Z-Pad area lead to drilling of Z-100. Z-100 came on production in March, 2004 at 4300 BOPD. · Evaluating a new multi-well plan of development for Z-Pad based on improved reservoir description from Z-39 and Z-100. · Subsurface analysis indicates a strong potential for development north of Borealis at future I-Pad. Examination of Texaco Prudhoe No.1 core shows favorable reservoir in the lower Kuparuk C and upper Kuparuk B Sands. An ice pad appraisal well is being considered for first or second quarter of 2005. · Action on an application is pending for the Borealis P A expansion to northward for future I-Pad development and southward for southern V-Pad and Z-Pad development. · Borealis booster pumps located at Z-Pad sanctioned and on-line October 15, 2004. · Uptime during 2002,2003 and 2004 averaged 75%, 87%, and 77%, respectively. · L&V-Pad trunk and lateral expansions sanctioned for up to 24 new wells per pad. · Began EOR with conversion of wells V-I 00, L-105 and L-108 to miscible gas injection. Pilot project started June 28, 2004. · Drilled and completed 6 new grass roots wells, V-Ill, V -117, V -114 Ai, V -119i, V-lIS and Z-IOO. V-117, V-114Ai, V-119i, V-lIS and Z-IOO were drilled and are producing/injecting under tract operations, pending the Borealis P A expansion approval. 4 of 1 7 ) ) Application for Borealis Area Injection Order Modification 1/12/05 · L-122 single well tracer test shows potential benefit to low salinity water flooding. · Work continues on Prince Creek (U gnu and Sagavanirktok) units as supply for future waterflood. The W-400 well startup October IS, 2004 proves Prince Creek deliverability of at least 20,000 BWPD. Development Drilling Exhibit 111-2 lists Borealis Region wells completed in the Kuparuk Formation by spud date. Recent development includes seven (7) development wells drilled from V-Pad: V-III, V-114Ai, V117, V119i, V-lIS, V-I06A and V-120. Wells V-III, V-lIS and V-117 are horizontal producers. V-114Ai is a horizontal injector. V-I06A is a horizontal sidetrack of V -106. In portions of V -Pad, horizontal wells are utilized to improve development well rates; vertical well V-IOO showed relatively low core permeability (6 md average) and low oil production flow rate (225 bopd average). An additional horizontal producer drilled from L-Pad may be drilled in 2004 or 2005. The lack of reservoir quality sand in Z-IOI had previously condemned the southern extent of Borealis. In late 2003, based on a new geologic and log model, the Z-IOO was drilled from Z-Pad. Z-IOO is a vertical well that logged approximately forty feet of pay and is producing 2700 bopd as of August 2004. As a result of this confirmation of the model, BPXA applied for a southern extension of the Borealis P A. Additional drilling is being considered for 2005 from the existing pad, including an injector to support Z-IOO. Additionally, BPXA is currently evaluating a proposed expansion of the Z-Pad, which would accommodate additional development of the southern expansion area. I-Pad (an ice pad currently in the permitting stage) will provide appraisal opportunities in the northern Borealis area. An appraisal well is planned for 2005. BPXA will continue to evaluate the optimal number of development wells and their location throughout the life of the reservoir. To determine reservoir limits, field extension appraisal has been concurrent with development well drilling. 5 of 1 7 )) Application for Borea1Ís Area Injection Order Modification 1/12/05 Projects Preliminary engineering has begun for the Z-Pad expansion, and permitting is under way for an ice pad for northern Borealis appraisal. Trunk and lateral extensions at L and V Pads have been sanctioned with construction underway. Booster pumps have been installed and started-up in October of 2004. These pumps increase water injection pressure and rate for Borealis. Water Injection Water injection started in June 2002. One well, V-lOO, was drilled as a producer and has been converted to an injector. Water injection distribution is provided as part of the L- Pad and V -Pad facilities. Produced water is being supplied from existing infrastructure to support the Borealis waterflood. Prince Creek source water may be used as additional make-up water as needed for injection support. The Borealis Owners intend to inject water at a voidage replacement ratio greater than one to restore reservoir pressure. Field reservoir pressure data is shown in Exhibits 111-3 and 111-4. Borealis Pool average reservoir pressure is 3004 psi at the datum of 6600' tvdss; this is the average of pressures measured in twelve wells in August of 2004. These data are in agreement with the Borealis simulation field model estimate of 3098 psi within original P A area boundary. A waterflood configuration with well spacing of approximately 160 acres per well is anticipated. Water injection is not contemplated for the L-112 area and the V-l08 area. Each of these areas is open to an aquifer of limited extent and drilling a supporting injection well is not warranted. Future development may include injection support as indicated by field performance. Booster pumps have been installed at Z-Pad to boost water injection pressures at L and V Pads and for certain Borealis wells at Z-Pad. The pump system is designed to increase wellhead water injection pressure while remaining within limits specified in the Borealis Area Injection Order. 6 of 1 7 ) ) Application for Borea1ÍS Area Injection Order Modification 1/12/05 Miscible Gas Injection Pilot First Borealis Oil Pool MI injection occurred June 29, 2004. Pilot Activity Summary & Learnings: Request was made May 28, 3004 to convert wells L-I05i, L-I08i and V-I00i to implement an EOR MI injection pilot program. Wells L-I05i and V-I OOi were converted to MI injection on June 29, 2004. Well L-I08i, due to a well tie-in timing issue, was not used in the Pilot. The main objectives of the pilot were to evaluate available MI system injection pressure and reservoir gas injectivity. MI was started with 3151 psi present on the V-pad header and 2845 psi present on the L-pad header. Since startup, the average gas injection pressure at L-pad has averaged just over 3000 psi. Both wells were placed on rates up to ....15 mmscfd. During the pilot, several facilities startup issues not related to the pilot program developed and injection was interrupted numerous times. Injectivity was confirmed as sufficient to handle the rates needed to provide both voidage replacement and EOR sweep in an effective manner. The Pilot is deemed a success and has led to submitting this application. Exhibits 111-5 and 111-6 show Wells V- IOO and L-I05 miscible gas injection rate, water injection rate, and wellhead pressure versus time. Well L-I 08 has not yet injected MI. Geologic Information 20 AAC 25.402(c)(6) The Geology of the BOP is described in Section I of the Pool Rules application. Exhibit 1-1 is an updated Top Kuparuk C Sand depth structure map. Exhibits N-l and IV-2 are updated NOPF and Net Pay maps for the BOP. Mechanical Integrity of Injection Wells 20AAC 25.402 (C) (8) All wells drilled and converted for injection service have been completed in accordance with 20 AAC 25.412, thus satisfying the mechanical integrity requirements as required by 20 AAC 25.402. Wells L-I03i, L-I05i, L-I08i, L-I09i, L-llli, L-115i, L-117i, L-119i, V-I00i, V-I04i, V-I05i, V-114i and V-119i will be converted to miscible injection service for the Borealis EOR project. The casing program for these wells was permitted and completed in accordance with 20 AAC 25.030. Exhibits V-I through V-13 detail the log and 7 of 1 7 Application for Bore<u.l Area Injection Order Modification ) 1/12/05 completion for these wells; injection well tubular has premIum threads to provide integrity during injection of MI. Prior to startup, or as directed by the commission, current injectors will have a commission witnessed pressure test to demonstrate the mechanical integrity wellbore and tubular. Each of the wells listed above have also been on water injection prior to this application, with full commission witnessed testing prior to being placed on water injection except V -119i which is scheduled to be tested during the week of December 15, 2004.. Cement evaluation logs have been run on all injectors (L-l03i, L-l05i, L-l08i, L-l09i, L- Illi, L-115i, L-117i, L-119i, V-lOOi, V-l04i, V-l05i, V-114i and V-119i) interpreted from direct measurement, cement is present providing isolation across and above the Kuparuk Formation. All drilling and production operations will follow approved operating practices regarding the presence of H2S in accordance with 20 AAC 25.065. Actual casing programs are included with the "Application to Drill" for each. API injection casing specifications are included on each drilling permit application. Injection Fluids 20 AAC 25.402(c)(9) Type of Fluid/Source Fluids authorized for injection for the BOP within the Prudhoe Bay Unit to enhance recovery and provide pressure maintenance are: 1. Produced water from Borealis or Prudhoe Bay Unit production facilities for the purposes of pressure maintenance and enhanced recovery; 2. Miscible Injectant from the Prudhoe Bay Central Gas Facility. 3. Source water from the Prince Creek Formation; 4. Non-hazardous water collected from well house cellars and standing ponds; 5. Source water from a Seawater Treatment Plant. 8 of 1 7 Application for Borealls Area Injection Order Modification ) 1/12/05 Produced Water from the Prudhoe Bay Unit Production Facilities, source water from Prince Creek Formation, and Miscible Injectant from the Prudhoe Bay Central Gas Facility will be used as the primary sources of fluids for pressure maintenance and enhanced recovery. Composition and Compatibility with Formation and Confining Zones The composition of PBU produced water and compatibility issues were addressed in the original AIO application. The composition of Miscible Injectant planned for BOP injection is shown in Exhibit VI-I. Exhibit VI-l also compares the Borealis crude oil composition to Kuparuk Oil. Miscible gas is a hydrocarbon with similar composition to reservoir fluids in the BOP therefore no compatibility issues are anticipated with the formation or confining zones. The composition of injection water from the Prince Creek aquifer is expected to fall within the range of Well W -400 and MPF-02 produced water compositions shown in Exhibit VI-2. Prince Creek water injection compatibility with the Kuparuk formation is established by: (1) analog Milne Point Unit F-Pad injection (1996-present), (2) analog Kuparuk River Unit injection (Prince Creek Source Water wells supplied 100,000-135,000 bwpd from Jan-1983 to Dec-1985 prior to the Kuparuk Seawater Treatment Plant started-up), and (3) the BOP Single Well Tracer Test performed from August 10 to October 4, 2003 on Borealis Well L-122. Maximum Injected Rate Maximum miscible gas injection requirements at BOP are estimated at 70,000 MSCFD. With increased surface pressures, maximum water injection requirements at BOP are estimated 90,000 bwpd. Injection Pressures 20 AAC 25.402(c)(10) The average surface miscible gas injection pressure for the project is estimated to be approximately 3100 psi. The estimated maximum surface injection pressure for the Borealis EOR project is estimated to be approximately 3800 psi. The resulting bottom 9 of 1 7 ) ) Application for Borealis Area Injection Order Modification 1/12/05 hole pressure will be limited by hydraulic pressure losses in the well tubing, with a maximum expected bottom hole pressure of approximately 5000 psi. Installation of a water booster pump, started-up in October of 2004 results in a maximum surface injection pressure of approximately 3000 psi during water injection. Fracture Information 20 AAC 25.402(c)(11) The Kuparuk River Formation at the BOP is overlain by the Kalubik and HRZ shales, which have a combined thickness of approximately 110 feet. The HRZ is a thick shale sequence, which tends to behave as a plastic medium and can be expected to contain significantly higher pressures than sandstones of the Kuparuk River Formation. Mechanical properties determined from log and core data for the HRZ and Kalubik intervals indicate a fracture gradient from approximately 0.8 to 0.9 psi/ft. Leakoff tests were conducted in Well L-IOO, L-l Oland V-I 00 to determine the formation breakdown pressure of the BOP suggests a fracture gradient of approximately 0.6767 psi/ft at initial reservoir conditions. These data agree with data from offset fields containing wells completed in the Kuparuk River Formation. The Kuparuk River Formation is underlain by the MiluveachlKingak shale sequence. A leakoff test in the Kingak shale formation demonstrated a fracture gradient of approximately 0.85 psi/ft. Miscible gas and water injection operations at the BOP are expected to be above the Kuparuk River Formation parting pressure to enhance injectivity and improve recovery of oil. Fracture propagation models and fracturing operations for stimulating wells in the BOP have involved injecting highly viscous fluids at high rates, 20-30 barrels per minute (bpm), and surface pressures at an average of 5500 psi. During both actual and simulated cases, the operations have not created net pressures sufficient to exceed the integrity of the confining layers. Conditions for planned injection will be at lower rates, less than 10 bpm, and utilize lower viscosity fluids. These operations will result in lower net pressures, and will not cause fracturing to occur through the confining layer. No evidence exists of out of zone injection for analogous Kuparuk miscible gas or high- pressure water flood operations on the North Slope. 10 of 1 7 ) ) Application for Borea1Ïs Area Injection Order Modification 1/12/05 Formation Water Quality 20 AAC 25.402(c)(12) The compositions of injection water from GC-2 and BOP connate water were provided in Exhibit VI-4 of the original AIO application. The composition of Borealis produced water will be a mixture of connate water and injection water. Fresh Water Strata 20 AAC 25.402(c)(13) Under 20 AAC 25.440, Aquifer Exemption Order No. 1 exempts those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit, including the entire Borealis Oil Pool. The Tertiary sands in the Sagavanirktok have measured total dissolved solids content of greater than 3000 mg/l in the BOP with calculations of water salinity from open hole resistivity logs acquired in the Prudhoe Bay Well E-16 indicate a salinity range of 40,000 to 45,000 ppm for Cretaceous and Tertiary Sands above the Kuparuk River Formation. Hydrocarbon Recovery 20 AAC 25.402(c)(14) Primary and Waterflood Recovery Estimates for original oil in place ("OOIP") for the Borealis accumulation reflect current well control, stratigraphic and structural interpretation, and rock and fluid properties. The BOP current estimate of OOIP ranges between 310 and 430 MMSTB. The extent of the range of estimates is due primarily to uncertainty in the BOP structural definition, oil- water contact and reservoir net pay interval estimates. There is no free gas cap known in Borealis. Estimated associated formation gas in place ranges from 135 to 200 BSCF. Primary and waterftood recovery is estimated at 100-130 MMSTB oil based on field performance reservoir modeling. A three-dimensional geologic and dynamic flow model of the Borealis accumulation has been constructed based on detailed stratigraphic and structural interpretation. This model provides the bulk reservoir volume and porosity distribution for the BOP. The model area encompasses the known extent of the Borealis accumulation. The model has 400 feet by 400 feet (3.7 acre) cells and is defined vertically with thirteen layers 5 to 25 feet thick. Faults and structural juxtapositions aree 11 of 1 7 ) ) Application for Borea1Ís Area Injection Order Modification 1/12/05 honored in the model through the use of comer point geometry and non-local grid connections. Water saturations in the reservoir model were established by capillary pressure equilibrium. Oil water contacts were varied across the pool based on available log data. Exhibit VII-l shows forecast BOP production and injection. This forecast includes improved recovery due to water injection and miscible gas injection. Miscible Injection Enhanced Oil Recovery Project The contemplated operation addressed in this application is a tertiary recovery project using the enhanced oil recovery (EaR) technique of miscible gas displacement to increase recoverable oil. It is estimated that implementation of the EaR Project will increase recovery by 5% to 8%, or approximately 18-25 MMSTB of oil for the Project. The project involves the cyclical injection of water alternating with injection of enriched hydrocarbon gas into the oil column of the Kuparuk River sandstone formation of the BOP. The miscible gas to be used in the project ("Miscible Injectant" or "MI") will be comprised of hydrocarbon gas, enriched with intermediate hydrocarbons, principally ethane and propane. The composition of Miscible Injectant planned for BOP injection is shown in Exhibit VI-I. Borealis wells are drilled from existing L, V and Z-Pads and may be drilled from a future I-Pad currently under evaluation. The Borealis EaR Project consists of an MI pipeline from the existing IPA MI line at Z-Pad to these pads and an on-pad trunk and lateral distribution system, and the conversion of Borealis water injection wells to water alternating gas (W AG) injection. Original water injection laterals were fabricated to meet WAG specifications. Therefore, the only surface modifications required to implement the Borealis EaR project will be to the header riser spools. Exhibit VII-2 shows the Borealis EaR MI distribution system. The west end MI line nominal capacity is 135-150 mmscfpd of miscible gas injectant. Injected MI fonns a miscible bank with reservoir oil through the exchange of hydrocarbon components, effectively displacing nearly all of the contacted oil, resulting in residual oil saturations significantly lower than with waterflood alone. Injected water 12 of 1 7 ) Application for Boreatls Area Injection Order Modification 1/12/05 helps maintain reservoir pressure, retards gravity segregation of the miscible injectant, and controls gas channeling. A completed slim-tube experiment defines the minimum miscibility enrichment (MME) of the MI and confirms miscibility of BOP oil with the proposed MI over the expected range of reservoir pressures. The MI source is the WOA IP A Miscible Gas which is richer than is required for Borealis miscibility. The experiments have been matched using a Kuparuk 12-component equation of state. Exhibit VII-3 shows BOP minimum miscibility pressure (MMP) with the injectant is 2150 psi as determined with the equation of state and consistent with the slim-tube experiments. Project performance forecasting is based on fine-scale fully compositional reservoir simulation using Well L-l 0 1 fluid properties and whole core reservoir description. The simulation model is a 2D cross-section kite-shaped model with 38 by 71 cells X-Z with l' thick layering and nominal 120 acre well spacing. The initial MI slug size target is approximately 7% of a type injection-producer pattern polygon hydrocarbon pore volume with a nominal WAG ratio of 1.0. The cumulative target size is nominally 20% of pattern hydrocarbon pore volume or 95+ bscf of miscible gas injection for the BOP, though MI injection parameters will be subject to adjustment as field conditions and performance indicate. After the cumulative target slug size of MI has been injected into the formation, pressure support will be maintained with water injection. Exhibit VII-4 shows model oil saturations at initial conditions, after one year of waterflood and after one and five years of miscible WAG injection. The BOP EOR gross efficiency is roughly 5 mscf MI per barrel of EOR oil generated. Without the BOP EOR Project injection, this MI would have been injected into mature IP A EOR patterns that have a gross efficiency of 26 mscf/stbo. The BOP EOR Project production and injection forecast based on this simulation work and scaled to the Project is shown in Exhibit Vll-5. The existing Kuparuk River Oil Pool EOR project has a history of success and is considered a good analog for Borealis. The Kuparuk River Oil Pool EOR project commenced in 1988 and has incremental EOR recovery of approximately 8-12% over 13 of 1 7 Application for BOreat¿ Area Injection Order Modification ) 1/12/05 waterflood. Analysis of Borealis oil samples indicates similarity to Kuparuk oil characteristics for bulk composition, wettability, and relative permeability effects. Exhibit VI-l illustrates the compositional similarity between Borealis and Kuparuk oil. The Kuparuk l2-component equation of state (EOS), tuned for Well L-lOl fluid properties, was used in the reservoir simulation. Relative permeability utilized in the simulation was derived from Pt. McIntyre core flood data. Surveillance Plan To ensure the efficient allocation of MI for the Borealis EOR project, rate and pressure response to injection will be monitored. Production fluid compositional samples will be taken at least annually to assess pattern efficiency based on the returned MI (RMI) ratio. Offset producers of injectors currently on MI can be sampled on a more frequent basis to help determine break through times and flood efficiency. Water injection surveillance will continue using pressure falloffs and other monitoring methods as required by patterns. Injection of water and miscible gas into patterns will be evaluated on a regular basis to address pattern performance and optimum injection rates to maximize recovery. Mechanical Condition of Wells within a One-quarter Mile Radius of Injectors 20 AAC 25.402(c)(15) Thirteen injection wells are proposed for MI service: Wells L-l03i, L-l05i, L-l08i, L-l09i, L-llli L-115i, L-117i, L-119i, V-lOOi, V-l04i, V-l05i, V-114i and V-119i. A map showing all penetrations through the BOP, and wells within a one-quarter-mile radius of the injection wells are shown on Exhibit VIII-I. A report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well is included as Exhibit VIII-2, with a copy of the most recent schematic diagram for each well included as Exhibits V-I to V -13. Mechanical integrity has been established for the subject wells based on calculated cement tops being at an adequate height above the injection zone to prevent fluid that is injected into the BOP from flowing into other zones or to the surface. Exhibit VIII-2 contains mechanical integrity data for well L-118 and V-115 that is within a one-quarter 14 of 1 7 ) ) Application for Borealis Area Injection Order Modification 1/12/05 mile radius the injectors L-119i and V -114i. All other wells are at a distance greater than one-quarter mile. However, static pressure and repeat formation tester data support the conclusion that the completions in offset wells beyond this radius are sufficient to contain high pressure fluids, including gas, within the BOP. Prior to any enhanced injection on wells without prior certification, wells will be demonstrated through established approved testing procedures, with a requested State Inspector present, to confirm mechanical integrity as required by 20 AAC 25.402 (e). Majority of the requested wells have been certified as Service Wells allowing injection. Dates for recertification are on file with the AOGCC. Although injection pressure will exceed average BOP reservoir pressure, reservoir modeling indicates rapid reservoir pressure falloff away from the injector during water and MI injection. Reservoir modeling indicates a radius of pressure influence less than 1000 feet from the injector at the end of the MI cycle. 15 of 1 7 ) Application for Borealis Area Injection Order Modification '} ; 1/12/05 List of Exhibits 1-1 Borealis Pool Rules and AIO Area 1-2 Top C Depth Structure Map with Borealis Wells and Offset Penetrations 1-3 GC-2 Area Facilities, Roads and Pipelines II-I Affidavit 111-1 BOP Production and Injection History 111-2 Wells list by Spud Date 111-3 Borealis Pressure Data 111-4 Borealis Pressure Data Trend 111-5 Well V-100 MI and Water Injection Rate and Wellhead Pressure 111-6 Well L-1 05 MI and Water Injection Rate and Wellhead Pressure IV-1 BOP Net Oil Pore Foot Map (CONFIDENTIAL) IV-2 BOP Net Pay Map (CONFIDENTIAL) V -1 L-103i Completion Schematic V-2 L-105i Completion Schematic V - 3 L-108i Completion Schematic V -4 L-109i Completion Schematic V -5 L-11li Completion Schematic V -6 L-115i Completion Schematic V -7 L-117i Completion Schematic V -8 L-119i Completion Schematic V -9 V-I OOi Completion Schematic V-10 V-104i Completion Schematic V-II V-I 05i Completion Schematic V-12 V-114i Completion Schematic V -13 V -119i Completion Schematic VI -1 Borealis and Kuparuk Oil and Prudhoe MI Compositions VI-2 Water Source Well W-400, MPUF-02 Water Compositions VII-1 BOP Production and Recovery Profiles VII-2 Distribution System for Borealis EOR Miscible Injectant 16 of 1 7 ) ) Application for BOrealIS Area Injection Order Modification 1/12/05 List of Exhibits (continued) VII-3 Borealis Oil Minimum Miscibility Pressure VII-4 Model Oil Saturation vs. Time VII-5 EOR Project Production and Injection Forecast VIII-l Map of All Offset: Wells Within JA mile of Injectors VIII-2 Offset Integrity: Wells Within JA mile of Injectors 1 7 of 1 7 I ) I I 4 3 2 I 1 ~~ 6 5 4 113 . ;t I ---.--.--.---.-.---.--..,-...-..--.--..-:.....--- ...-....--.---...--.-...----.---.-.".--..--.--.--.---------.--.--... .-----.-...-.-..--.-.---..---------,..--.---...-..---..---..--~__..___.J , It ' o ! i 10 ' 2 w w o ..- a: a: 6 ) 5 11 '12 7 8 9 10 11 12 7 8 9 14 13 18 17 ~ I 15 -1~----~:' -:~ - :19 15 20 i 21 141_~--23 --- :-- 3 1280 AC -I 04 744~,' '2448 ACf04 744 7 2~ ','" ' , '~' I ;, I L, I 25 30: 29 I 28 27 I 21i-- 25 t7--.-____J-. 1 ß·--~·-·----1-9 I 31 32!1 33 :$4j 35 047449 1868 AC 028239 2560-ÄC~ 028238 I! . Ii :3 ~ 2 ~ ' ·--·--·---..-&1----·-----~_-.:.::~'"":u;.;---5Ð-·--··--·--·-.-· 49--- ~l 4iO Ii '\ 9 ~ 1-1\ 12 7 8 9 028241 256?5~~?28240' 2~.~0~C:_04;;450 2469~C~2ß261 2560 15 14 13 18 '54 17 "'. 640 AC, :/ 1840 AC I ~ 58'----r-"--:~-' r '54A 'I ! 22 23 24 19 ~ 20 ¡! 21 55A 22 ~ ,028245 1920 AC 028262 II, 640 AC j 028263 1280 ACr, ~ 82 I 25 640 AC ~ -., 16 1 ~) , , 1L40 AC "2 11 1 20 21 X 028255 028256 1040 AC ~ 23 025637 26 T12N T11N 2 6 5 4 28 27 ~ ·,·20---------t----------,,··-2-1-------··--- 36 L 32! 33 34 ¡ 2560 AC, 0282:-9 , 2459 AC~ 028258 2560 AC ! 5 I 4 .:30 29 _.,--- .~'"-"--'-'.~._.."._--,,_.__._-_.,..__....-_. 35 36 6 11 7 16 14 15 23 24 19 21 028244 .----,--- -·--·----·--·-··-r·..-·---'···------·- .,.--, -..,.-.-.-.-----..--.-..---.--. --.- 1_~61 25 30' 29 28 27. 26 i ---r------------------------~¡--- 35 I 36 31 32 :5.3 34 35 I - 028246 I I ' 2 I 6 5 14 3 12 6 ------1-- ---------. -- -J---- -----------1- ------- - - --- 1 I I ' i [11 1 12 "7 I 8 I 9 I '10 I 11 I 12 7 8! 9 ~--------~-----.-----+---+-..---~---J.-.-J--.---_.--_.._._¡__.__ __ 047454 1920 AC I I 0 2 miles ,I I I I 114 I I I) I 15 I ~----+ _ PAUDHDEBAYUNITBOUNDAAY ~t-----j BP EXPLORATION (ALASKA) INC. I 80 PBU TRACT NUMBER I 1 2 :5 I 028288 ADL NUMBER "1 I '22 , I -.-- LEASE BOUNDARY I I -1-----+ n BDAEAUSPOOLAULES&AJDAAEA -ì----+ Exhibit 1-1 I 26 ¡ 25 30 I 29 i 28 I 27 I Borealis Pool Rules and AIO Area +-----t----- --t-- --i--- __L_ --T 1 35 I 36 31 I .:32 I 3:) II 34 I I I I I I 30 29 23 2.7 ·-··-81-·------·-t--·----··ae····----··----t 36 31 047453 32 33 34 2491 AC 047452' 2560 AC I 'ì , T11N T10N 5 4 3 ß3----·~- 10 DATE: April 2004 SCALE: 1:110,000 Exhibit 1-1 Im14534.dgn ) Application for Borealis Area Injection Order Modification EXHIBIT 1-2: Top Kuparuk C Map with Borealis Wells and Offsets, CI=25 ft. . ~ . Borealis producer Borealis injector Other Kuparuk Penetrations 'i I ) .il t\ ~ ~ 1C-14 . -.ao . MIG 'lJ'-!:>'( . ~ 'T \~ ~ ~.. ~ /~\ / \ // \ ~ \ ------,-/ ...._1_17_11_11 ,~ . ~/ - ~ 1C-12 . "It G Application for Borealis Area Injection Order Modification 1/11/05 , r PROPOSED I PAD ~ \ \ ')(-. ó o I 1 I Exhibit 1-3: GC-2 Area Facilities, Roads and Pipelines n J / , ~ a: 0 i '-...-I ell ~ -~ ttR ,~~ SPAD 2 I LPAD~ <~;/~//j~-- -- L£~_j d \ ø MPAD GC2 ~PAD '-"- ø ~,.- 3 Miles I .~_/>/~ -- ---- "--_.------ -- - _._--------~-~-~ -' __~ ..__.. --.1-- ) Exhibit 11-1 Affidavit ) STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Gil Beuhler, declare and affirm as follows: 1. I am the GPB WEST Manager for BP Exploration (Alaska) Inc., the designated operator of the Borealis Participating Area, and as such have responsibility for Borealis operations. 2. On \. J tA. V\. ~^ 'y-~ ') / ~. òlO 05""- , I caused copies of the January 12, 2005 Application for Modification of Area Injection Order 24 (Borealis Oil Pool) to be provided to the below referenced surface owner and operators of all land within a one-quarter mile radius of the proposed injection areas. Operators: Prudhoe Bay Unit Operator: BP Exploration (Alaska) Inc. Attention: M. Johnson P.O. Box 196612 Anchorage, AK 99519-6612 Milne Point Unit Operator: BP Exploration (Alaska) Inc. Attention: D. Nicolson P.O. Box 196612 Anchorage, AK 99519-6612 Kuparuk River Unit Operator: ConocoPhillips Alaska, Inc. Attn: Fy-CAV"\ k :::r 0\\ e.s P.O. Box 100360 Anchorage, AK 99501-3510 Surface Owner: State of Alaska Division of Mining, Land & Water Department of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3510 ~~ Gil Beuhler ../--/-- y ('Y05 Date ) Exhibit 11-1 Affidavit } Declared and affirmed before me this \ ~ day of ~~~~ ~ ' 2005. ~'I'~ '\~,,~~~ Notary Public in a~ for Alaska My commission eXPires:~. ~ \ ~ Application for Borealis Area Injection Order Modification 70000--- - ?( ~ ~ 60000- 11 0:: '8 ~ ! ?( ~ t- If) I) 1i 0:: ~ ~ l ?( Q II) t- If) I) 'Ii 0:: '8 Q: 50000 - . 40000-- 30000 - o ?( Q IL U If) ~ 20000 ---- 1i 0:: 1:1 o Q: ø CI o ?( Q IL 0: ::IE I) 1î 0:: ~ 10000 _. ~ 0 1/11/05 Exhibit III-I: Borealis Production and Injection History - - - BORULIS_BRLS CìIRI - BORULIS_IiFlLS GPRI - BORULIS_BRLS 0PR1 - - - BORULIS_BRLS'W1R1 - BOREALIS_BRLS \o'PR1 j I _ ._._.___.m..m+_..m_________._.___..~_____m_t--.-.-m~-~. _ _._.______ ..____m_____.m. 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':-. t.:~ r. --; - -\j {i04.- - ~- -- -m-----r ~l 'I" ~r---u-.ç-11--T ~~'----_··--I-I. ltt ",,,,,' tt~·,it¡?---, t· ., ~ ¡,. -~¡i,-, ~L ---l-----it- m___ ---I ;t k~r~'+, ..------ -- - -. ft- ~~~ì MI ~)R - ~ ,\ I,\'I~ I I II l' I ' h I~i~::'~ ¡ .. - ~. - - - - as- ---- -,/-t- Î:j-t -f~-- -~--- ~----------Ltl-- ------ - ----- r-l:--- -~- --~-~~--- --------- --- !--r-~rt-!-1-ûas~. 1jection , , \~1 I I I ! I "1 . I i J ~,I ' I ¡ , h I ~. ! - - ---, - .. -' ! I'~- ---- -~. - - - -- ----..-»-.> ------------.+---- ~-ij-!---·..-,..· -f-,w'--r ~' i. ~ I'~II I II I .. I III' ' .J '_ _' _j_ .. ~ _ I' . , - - - - - -- -' ?nn? ?nn::! ?nn!1 ?nn4 ) Application for Borealis Area Injection Order Modification llll/05 Exhibit 111-2: Borealis Region Wells completed in Kuparuk Formation Borealis Participating Area Wells, by Date API Number Spud Date Well Type 500292286500 03/09/1998 Oil Producer 500292285801 04/01/1998 Oil Producer 500292300800 04/29/2001 Converted to WAG Injector 500292302500 07/02/2001 Oil Producer 500292302800 07/16/2001 Oil Producer 500292303200 08/04/2001 oil Producer 500292303600 08/18/2001 Oil Producer 500292303900 09/13/2001 Water Injector 500292303500 10/07/2001 Water Injector 500292305500 01/03/2002 Oil Producer 500292306000 01/17/2002 oil Producer 500292306400 01/31/2002 Oil Producer 500292306900 02/21/2002 Water Injector 500292307100 03/07/2002 Oil Producer 500292307700 03/27/2002 Water Injector 500292307400 04/17/2002 Oil Producer 500292308300 05/01/2002 Sidetracked to V-106A 500292307000 05/14/2002 oil Producer 500292304600 05/30/2002 Water Injector 500292309000 06/18/2002 Water Injector 500292307500 07/05/2002 WAG Injector 500292310100 07/26/2002 Water Injector 500292310300 08/14/2002 Water Injector 500292309700 08/27/2002 Water Injector 500292311200 09/11/2002 Oil Producer 500292311700 09/23/2002 oil Producer 500292310800 10/08/2002 Oil Producer 500292312000 10/16/2002 oil Producer 500292312500 12/08/2002 Oil Producer 500292312900 01/01/2003 Oil Producer 500292313801 03/14/2003 Oil Producer 500292304300 03/22/2003 Oil Producer 500292314700 05/19/2003 Oil Producer 500292316100 07/02/2003 Oil Producer 500292317801 10/21/2003 Water Injector 500292319500 03/15/2004 Oil Producer 500292320100 04/04/2004 Water Injector 500292322500 09/18/2004 Pre-Produced Water Injector 500292308301 10/01/2004 Oil Producer Name L-101 L-IOO V-IOO L-116 L-I10 L-114 L-I07 L-117 L-115 L-106 L-104 L-120 L-I11 L-102 L-119 V-I01 V-I06 V-102 L-I09 L-I08 L-105 L-103 V-I04 V-105 V-108 V-I03 V-I07 V-109 V-113 L-112 L-121A L-118 L-122 V-111 V-114A V-115 V-119 V-120 V-I06A ) Application for Borealis Area Injection Order Modification Name Z-IOI V-117 Z-IOO ) l/ll/05 Exhibit 111-2 (continued) : Borealis Region Wells completed in Kuparuk Fo~ation Api 500292297800 500292315600 500292318200 Regional Wells, Spud Date 12/15/2000 05/30/2003 11/24/2003 by Date Well Type Tract Well- Shut-In Tract Well Oil Producer Tract Well oil Producer Application for Borealis Area Injection Order Modification 1/11/05 Exhibit 111-3: Borealis Pressure Data Well O,G,GI, Final Test Shut In Pressure Depth Tool Final Observed Datum Pressure at Name and. WAG,WI Date Time Survey Type B.H. Temp lVDss Pressure at Tool lVDss Datum No. Hours Depth V -102 0 08/25/04 372 PBU 152 6263.77 3331 6600 3472 V-117 0 08/25/04 493 PBU 150 6505 2858 6600 2898 L -1 02 0 08/24/04 426 PBU 152 6294.22 1964 6600 2092 L -1 07 0 08/24/04 336 PBU 152 6248. 13 3419 6600 3567 L -120 0 08/24/04 434 PBU 151 6303.15 3341 6600 3466 L-100 0 08/23/04 509 PBU 157 6400.42 3507 6600 3591 L-101 0 08/22/04 481 PBU 150 6226.01 2544 6600 2698 L-110 0 08/21/04 138 PBU 159 4868. 17 3604 6600 3656 '.-, V -107 0 08/21/04 293 PBU 151 6337 2376 6600 2452 V -108 0 08/21/04 275 PBU 155 6409 1933 6600 2008 V-101 0 08/20/04 PBU 153 6600 3470 V -103 0 08/20/04 304 PBU 154 6429 2601 6600 2674 2-100 0 05/18/04 222 PBU 151 6490 3225 6600 3269 V-115 0 05/02/04 73 SBHP 152 6531 2783 6600 2807 V -114A 0 03/12/04 757 SBHP 150 6552 2911 6600 2931 2-100 0 03/09/04 24 SBHP 148 6624 3251 6600 3243 L-116 0 02/03/04 264 PBU 154 6085.42 2860 6600 3029 L-122 0 01/16/04 24 SBHP 6070.49 2918.7 6600 3151.7 V -1 06 0 01/12/04 24 SBHP 153 6600 2117 6600 2117 V -105 0 12/01/03 SBHP 4275 1858 4400 1913 V-111 0 11/02/03 22 SBHP 154 6580 2788 6600 2795 V-117 0 08/21/03 135 SBHP 152 6609 3104 6600 3100 L-122 0 08/11/03 249 SBHP 160.4 6646.04 3161.9 6600 3139.8 V -100 0 08/05/03 504 SBHP 151.4 6600.25 2617.7 6600 2622.6 L-101 0 06/12/03 1271 SBHP 156.2 6523.22 1930.7 6600 1978.7 '~ L-114 0 04/22/03 58 SBHP 159.6 6499.42 2543. 1 6600 2584 L-104 0 04/21/03 111 SBHP 152.4 6498 1831.3 6600 1844.6 L-106 0 04/20/03 80 SBHP 157 6563.33 2096.5 6600 2109 L-118 0 04/20/03 72 SBHP 152.7 6380.25 2591.8 6600 2687.8 L -120 0 04/18/03 87 SBHP 154.5 6499.94 2041.5 6600 2049.8 L-121A 0 04/18/03 60 SBHP 159 6623.36 3008 6600 2997.9 L-101 0 04/17/03 80 SBHP 156.6 6545.89 1702.7 6600 1733.9 V -109 0 03/24/03 202 PBU 6393 6600 2779 L-112 0 02/19/03 144 SBHP 161.1 6599.26 3394. 1 6600 3394 V-113 0 02/03/03 SBHP 155 6600 3050 6600 3049 V -107 0 01/25/03 79 SBHP 153 6517 2960 6600 2994 V -103 0 01/16/03 SBHP 6600.09 3093.6 6600 3093.5 V -109 0 01/11/03 SBHP 155 6517 2728 6600 2764 V -105 0 01/07/03 SBHP 157 6599 2885 6600 2886 L -1 08 0 01/04/03 SBHP 158 6599.53 2108.8 6600 2108.9 V -108 0 12/02/02 SBHP 156 6600 3235 6600 3235 L -1 03 0 11/09/02 204 SBHP 154.8 6599.33 2268.5 6600 2268.3 L-107 0 10/01/02 500 PBU 149.5 6269.38 2197.9 6600 2289 L-119 0 10/01/02 PBU 6600 3202 L-111 0 09/27/02 309 PFO 144.6 6309.88 2573.3 6600 2512 L-115 0 09/27/02 310 PFO 139.2 6237.56 2624 6600 2509 L-117 0 09/26/02 291 PFO 134.9 6251.56 2685.1 6600 2454 L -1 00 0 09/25/02 289 PBU 156.3 6411 .04 2140 6600 2209.9 L-101 0 09/25/02 289 PBU 147 6233.83 1902.76 6600 1929.9 L -1 02 0 09/25/02 286 PBU 149.6 6312.14 2469 6600 2654 L-104 0 09/25/02 289 PBU 146.5 6335.95 2116.6 6600 2165 L-106 0 09/25/02 285 PBU 155.4 6309.39 2011.5 6600 2060 L-110 0 09/25/02 313 PBU 157 6471.31 2439.8 6600 2571 L-114 0 09/25/02 289 PBU 154 6333.03 1949.4 6600 2212 L-116 0 09/25/02 289 PBU 142.6 6068.47 1752 6600 1898 L -120 0 09/25/02 289 PBU 150 6316.83 2229.9 6600 2347 V -100 0 09/25/02 290 PBU 151.9 6448.32 2500.3 6600 2715 V-101 0 09/25/02 290 PBU 152.5 6322.91 2114.1 6600 2137 V -106 0 09/25/02 290 PBU 153 6412 2492 6600 2475 ~ V-104 0 09/23/02 SBHP 155 6600 2583 6600 2583 L -1 05 0 09/22/02 214 SBHP 157.6 6600.34 2252.7 6600 2252.5 L -1 09 0 07/17/02 SBHP 158.7 6599.26 2825.5 6600 2828.9 V -1 02 0 06/27/02 SBHP 157.3 6599.4 2805.8 6600 2806.5 L-119 0 06/19/02 550 SBHP 157.3 6596.01 3201 .8 6600 3203.3 L-117 0 06/08/02 719 SBHP 158.8 6599.72 2763.8 6600 2764.5 L-115 0 06/06/02 1217 SBHP 158.8 6600.22 2552 6600 2551 .9 V -106 0 05/30/02 SBHP 156 6600 3169 6600 3169 V-101 0 05/06/02 SBHP 155.8 6599.93 3014.5 6600 3015 L -1 06 0 04/17/02 55 SBHP 156.6 6499.35 2817 6600 2840 L -1 02 0 04/11/02 SBHP 155.7 6599.11 3384.6 6600 3385 L-111 0 03/21/02 SBHP 6599.49 2951.4 6600 2951.6 L -120 0 03/19/02 SBHP 157 6611.78 3149.4 6600 3144.2 L -120 0 03/17/02 SBHP 156.3 6611.78 3199 6600 3193.7 V -100 0 03/14/02 SBHP 156.1 6605.15 3351.3 6600 3350.3 L-104 0 02/28/02 SBHP 157.6 6597.92 3259.4 6600 3260 L -1 06 0 02/10/02 SBHP 163.6 6896.3 2865 6600 2706.7 L-100 0 11/30/01 99 SBHP 158.4 6579.58 3023.2 6600 3030 -' L-101 0 10/24/01 SBHP 149.9 6400.03 3379.9 6600 3466.5 L -1 07 0 09/20/01 SBHP 158.7 6622.55 3504. 1 6600 3494.2 L-110 0 09/17/01 SBHP 160.7 6629.13 3451.3 6600 3438.8 L-114 0 09/16/01 SBHP 160.3 6571 .89 3458.4 6600 3470.8 L-116 0 09/16/01 SBHP 157.8 6600.33 3468.5 6600 3468 2-101 0 06/12/01 PBU 148 5407 3333 6600 3386 ~-~----,~~ ) ) ) Application for Borealis Area Injection Order Modification 4,500 4,000 3,500 -, 3,000 E 2,500 ::1 .. C'CS "'C @) .- 0 2,000 c. 1,500 1 ,000 500 1/1l/05 Exhibit 111-4: Borealis Pressure Data Trend o 04/19/01 12/1 0/02 06/28/03 01/14/04 08/01/04 02/17/05 11/05/01 OS/24/02 ) -....- L-100 · L-101 L -1 02 X L -103 --* L-104 · L -1 05 + L -106 - L-107 - L-108 L-109 L-110 L-111 x L-112 3K L-114 · L-115 L-116 - L-117 - L-118 ~, L-119 L -120 A L-121A X L -122 )t( V-1QO · V-101 + V-102 - V -1 03 - V-104 -+ V-105 .. V-106 .. V-107 "X V-108 )K V-109 o V-111 + V-113 V-117 V -114A V-115 . Z -1 00 . L-01 --J(--- L -02 x V-03 Application for Borealis Area Injection Order Modification 1/11/05 Exhibit 111-5: Well V-tOO Miscible Injection and Water Injection Rate and Wellhead Pressure ~ Q m t- (I) G) 15 ~ 'E' - V-tOO_BRLS WIRt - - - - V-tOO_BRLS WHP1 I i ¡ _-..w.__.._____ -i- -- .- ------".-~___j-------~~-----~~,,--~--..N~-·~-~r·--~-----~-~-~~---~~--..-.--"----~--.-------- 4800 [¡ t t ! ::=-~~f=~~:=~=~t~=~~~~~~~~~-~-i-~OO __ -----.---~ -.- -~'-'---'" -~--_.----..----,~-! . .---------,-----~~----.-.---~~.--- -- t-_H- __~_____J_.___..__._____________j~~___~__._~___~..~ 4000 ! i ! ¡ -- II 7000 --- -""'- .u.. _...:---- - __.__.._._.__.L___________,.~!_____----~---~----L----- .-.--- ' --- _____~__~________~__~__~~.I.!__._ ! ! ! I -.- I: - - -- - ~ .n -- ,_______·__·".._t_·___·_..____·_~__·_________I____~_______---,--------Jr--~--- ~-..... -.-.----~- --..--~~,~._----,~-._,~,,--~..~..---~--~~~-.~.-.-~---- 3600 i !: ¡ J :: ~ 6000 ~ :..___. --~r- -~ --= -- ~-¡ . ~-:~--~~-~~--,---~- ~ ~---~=~ r~ ~~: ~T -- =~=~~:--=----= -~+~- --:=~--:----{--= 3200 i 5000 ------.---. -r - - -------r - .--- - -------- --------- -- --------- __1: --------- ----- ------- ----------------------------~--------- ------:'----- ~ 4000 ~==--~ì- = - --- -==J-- --~=-~------ -- ~---- -- ::-== -r' ~---- ---=--------- 't-- ..1t· 2800 i !! ì I (I" f II I I, ----.-----,--- .---- I ,. -~..-+-----_.;Ji;-~1'"....... ~..I ..I"II~I ..~2400 ¡ ¡ . ¡ ~ I I I 1.1 I"', 3000---·--------t-- _--..-'-~-+--~w~-.~----~.~---~'~~-;~-.J ~+: I .1 :~: :l~!~: ~ ~ ! ,! . 110... ! I I t I ~ II :f ~_·_-------1-~----·--~r-------~--~~7-- .. Illt-; r ~. ..--2000 2000~_-~-L--------t-----~--r-'-' .. _ -if-'-J- :. ... :::.---i~--_t_=+-- 1- I I II, . , I I I I II. I I r' J -.------------:- . - - - ----r-. ¡ --~:;. ¡ ~:; ~ : -,' ~_: ~ ".' ~. 1600 '~! ! II,: I~~ ' II I ;.N. ~ 1 000 -------rll-------l----·~---I- -.~ ;"~ r : 11 J - --"'-- ------------1 -.----+--.----+------+. ---~. .. I : , -'-1200 11 i ¡ ¡ ,; , I o ¡ ¡ ¡ ,¡ J Anr MFI\I ,Iun ,Iul AlJn f=:p.n Ort -- 10000 - V-WO_BRLS GIRt '-" L.. i ~ Q LL. U (() ~ G) 1i ~ 'E' (¡) as o Nn\l ) Application for Borealis Area Injection Order Modification , ,~ ~\ , " þ ....-.-.. , ........ ALKJ:92 ADL 2,242 "_1_17_11_11 . Ie-II . Exhibit IV-2: Borealis Field Net Pay Map CONFIDENTIAL ALK3814 ADL 28243 ALK2293 ~DL 28244 t ~ ........ . , ;Z4000 KlLOMETtRS ~o KILOMETERS 'E MILES H -ù ~o STATUTI MILES ~ --'U- _ . EXPI.CIIIA1ION IAI.AIIKAJ 1Me. Borealis Net Pay Contour Interval: 10ft JANUARY 20, 2004 1- 1- U"""AN-2004 I I ) Application for Borealis Area Injection Order Modification ) 1/11/05 Exhibit V-I, current schematic of L-I03i TJIU!! - ~ 11'1:6'" CIW waJ.H!AO - fr.c AC1'U\ TOft - fo¥\ KB. aev - 71U' BF. B.£V - 53.4' 'kOP - 5aD" Mille Angllt - Sf¡ '. 4013' DaIIIm MJ - ð958' baIum I\ID - ti6ÐD' sf I 9-511" CSG,4DJ;, I.-ea, ,D - a.835" H 3031" ~ Minimum ID == 2.813" @ 8510" 3-1/2" HES X N PPLE 1 4-V'2- TBG, 12.6f. L.eo, .0152~. ID - 3. 9S8" 1-1 5779" I I ~1/2' 1'813. 9.21\1. L-aD. .tDB7 ." 10 - 2SQZ" I I 3-1/2" TBG, 9,;2¡1i, L-80', .1JJ87 qJI', 10- 2..99'2" H 8579' ~ peRFORATION SlMM.AftY REF LOG: 1t:P PERF ANGle A TTCfI' PeRF: 520 sase.' Hote: IW8' I) PnJc:Uc:,Ilon œ Þr nt&lDI1œIJ pelf øata SI2! SPF' JNT!RVAI. O¡:nJSq¡ 0\1E 4-õ,'ö"·50 5D95 - 5962 0 OðI\l'9œ 4-5.1ð·" -5< 6018 - eoro, 0 0II,t!9tÐ2 4-5.'8".s- 6091- 6119 0 DBI'D9tÐ2 4-5.q" 5, 6194 - 521G 0 DBltI9.02 4-5.18"5 62ðS - 5372 0 OSi0Kr2 4-ð.1ð".s. 6399 - 6415 0 DBI'D9,'D2 I Rt'TD H 9215" L-1 03 SNETY NOTES: GLM'S. STAWI & #rl ME 3-trr X 1-112- MMG-Ws. \'filCH ARE WAJERFLOOD MANDRELS. =---i 1019' H 9-9" TAM FIORTCOUA R I I . I 221C' H 4-1.12" te X NIP; D- 3.813" I .. G\S LFT MANDRELS I: ST P/O 'NO œv 'l"VPE YLV LA 1CH PORT OAT! 5 4!-13 35m 51 i\:8Go2 [lMY eK 16 11110.'112: 4 531D 4D[B so KBG-2 DM'f eK n 1Dl1~D2 :3 564S 42& 4.7 iœGo2 DMY eK ::æ 11l1o.'C2 WA 1EfIFLOCO MANt:'.ft!L.S ST P/O NO œv 1'VÞe YLV LAltH PORT DATE 2 5II:u 4J48 kt MMG-VÎ DM'f i'« 1:1' œ"w,olIZ 1 5862 43EI6 52 MMGW [lMY RK Q œ.G'œ - - I r :8: X>-f I ~::J i 1 ~ I 1" CSG, 2M, L-80, .0383 Þpt', 10 - 6.276" H 9380" ~ 11! ReI BY OOt.&£NT'S 0IIItlit'G2 ElM<AK OImN\L Cor..R.E'I'1:fo¿ 10n3c'02 .B'KAK GlV ClO 12/31Ch'02 MCt<K GlV ~ O4,NI03 CftSIfP '1V)'t.C) OCftftI!CTIONS Di':œ Pel 8Y ~ 5711' H 4-1!2" liES X NIP, D - 3.6'3" I 5722' H T X4-1.1Z SKit Pf'BfEft PKft. 10 - 3.875" I H 401i'Z' XJ..1.12" )C, ,1'1) - 2.99,2" I 5719" 8510' H J.1i'Z' foŒS XNP, PI) -2.813" I 8521' H J.1i'Z' X4-1.'2" )0. iO - 2,930- I 8522' 1-1 7" x.c-lIo'2" BKI\ s.3 PKft, D - 3..875" I 8526" H 401i'Z' X~1.'2" )D. if,) - 2,99,2· I 8548" H 3010'2" tES XNP, to - 2.a13" I 8569" H J.ur HES XNP.IO - 2.8113" I 8581" H 3-11'2" WLEG I 1----1 86291 H ..,. ~NŒflJTWI RA. TAG I f--i 8933- H T' WI/eRJTWI M TAG I 60ÆA I.S lHT vtaL: 1.-103 PBMJ'Na: 202t39D API No: 5D-029-231D1-00 see 34. T12N. F\111!. 2!90' NSt. &3ð1ð' Y.e.. 8P EXploration (AIIIU) '~ ,I Application for Borealis Area Injection Order Modification ) 1 /11/05 Exhibit V -2, current schematic of L-I05i TJIIf!!. 4-'1(16" ClN WI!!..~O- Ff.c AC1lJATOR. · ,.,.,., K8. ELeI · 18.8" !If. al!l- 24.94" KOP- 41Xr flax A IÇIe - 46".644&" DalUm Þ.tID - 8156" tJalUm 1'1 D - 661:0' SS 1 9-S'8-'CSG. 4QIII, L-eD.Ð-.fI.8-35- H 2856" ~ Minil1lJrn ID = 3.72:;" @ 7873' 4-117" HES XN NIPPLE I 4-t,Q.*1&G,. 12.61J, L-eo. .D1:!2: pI', D -3.!i56M H7884' PERFOftAroN SUMtAM'Y 1œF LOG: S,QLeEæ P!pt: ~!CORC MlGLf ATTOPPEfI!f': 34.0771:0' Note: Aárta PIrDIbcIIan œ 1IJ' Nltancà perfGiltil SIZ!! SPF ~tfÆRV"'L OX!i'Sqz DATe: 4-1(2- 6 1100 - 7122 S 01(17/02 4-1'2- 6 17as -1805 S 07.1'17/02 ~-9. 6 811'12 -æ32 0 Oet1ð'D2 4-112- 6 811-23 - 81143 0 07.(17/02 ~ð· 6 ,!1114J - ·11II'74 0 Oet1ð'D2 ~.fI. 6 !It Q( - 8110 0 01!lCJ7.'02 I ~TO H 8267" I rcsG,. 261, L-æ.ID-I!i.2~" t-t 8350" ~ TI! ÆV 8Y COtofrÐll's 07.t'2D'02 lWNKK ~IGIU\L caMll!llON œ-I'Cl&02 AU" GL V lJI:IO\ 1'! [8¡'18iG2 .LJt(K ADFlEftfS 1Df13102 .BIKAK GLV C.'O D4..1'CI&,QJ tftS'TP "1vo.'r.ÐCOIW!:TCNS L-1 05 SAFETY NOTES: :-I 98Ø' H 9-S'S· TA M PCftT ca.LAR I I I I 2194' H 4-1/r I1!S x MP, 10 - 3.813- I .. G,tS. LPT Þ.6\NOÆLS L ::¡-, P4J ¡\I'D De\l' üll'ijoI¡: \IlV LA ¡~H Pert I [),I\WI: J ~15 3t,e) 41 K~G-2 OMY ~K CJ 10,f1311J:¿ 2 523S 4496 42 K&G-2 OMY EM< 0 D7.f2r1Q2 1 1559 15186 31 K&G-2 OMY EM< 0 10,1131'02 ~ I I :8 8 I . . :g ~ ~ \ DAT! REV BY cor.M!NTS 16351 H 4-1/Z" teS X NP~ D - 3..&1-3- 1 1646' ~ T X 4-11'2- 5KR PiÆl/ER PKR. 10 - aa9" 7811' H 4-t,'Z" !!£S·X NP; D -3.-111-3"1 1828' H T X4·1/rI!ICRS-3 RCft, 10-3.875" I 1852' H 4-1,tZ" tESX NP. D --3.·913· 1 1813' J-I 4.-1."Z' I"'.eS)N NP. ID- 3..725-- 188' Ii 4.-1.12" WLfG.D - 4.00' I 1904' H 7" - X:æ P\.P JTWI !VI. TAG (!L.I'to') 8045' H 7" 2e1¥X:æ P\.P JTW/!VI. TAG (!!L.I'to') 5~1S Utfi' \'Ið.1.: L-1D5 R!IVtofTNo: 202JS3D A~ No: E-D-D2g.23J7~OD seeM. T12N. R11E 241'!' ~L& 3673' 1/6. !II erplorlilon (AlaalCa~ =---I 1018' H 9-:5'8" TA M P'.:1IU ca..LAR I I I 2237' H 4-1.'2"' foES. X NP,IO · 3.813· I -'sr 1'110 GAS UnM"N~LS L Me DEV TY'PEYl.V LA1CH PORT' DATI! 5 3818 JS:IO æ KBM OMV' EI<..s Ð' D11DW3 4 4119 JaJO æ Kl5M OMV' EJK..s (I> D1.i'œ'02 3 4&93 4i250 43 IœM OMV' BK..s ,I) 011'Q4lO3 WAT!RFL.()OO Ml\tlitREI..S SiT MO "NO DEV TY'P! VLV LA 1CH PORI" DA1!: z 41167 4251 41 MMC...w OrM RKP Œ Oi JIJ401' 1 4926 4334 4D MMGJN OMV' RKP Ð' D1œ'02 I 4158' H 4-1/2" I"ES X NP,ID -3.813- I ----14762" -4788' t- 4~ 1fl" Mefti.A PR4 TeG AP\ TCH, P - 3.235- 8 1 4769" -I 7· X4-112"' !SKit PREMIER PK!\. 10' - 3.m· B I 4825' H 4-1,'2" X 3-1/2:" XO, ;0- 2.9'æ" I ) Application for Borealis Area Injection Order Modification Exhibit V -3, current schematic of L-I08i TR:i!- 'Nla.LHeAD- AC1U\ '!'OR- K8. a.ev . SF. a&' - KCP- \tuc .An!e . OillUmMD·· OalumTVD- .1,'1e"clW Ft.C tit. 78.4' NA 30a 43 . 4672' 1811' eeoa SS L-1 08 :::: I 'i-Sle·csG. 40#, L-eD,O--8.ø" H 2120" rJ Minimum 10 == 2.15" @ 1548' 3-11211 HES XN NIPPLE I ::I I 4-1/2"T!G.12..61¥. L.aD, .0152 ~r,ID -3.938" H 4825' g :I ~ ::ï 3-11'2· T&G. 9.2f', L-OO,,COð1 ~f, to -2.992'" H 1558' I ] J I N '\ P!RFOAAIDN SUMMA.R1 per LCG: TI:P P!RF A.t\GL! A.TTOP ÆRF: 40 @4!šEð' Nc:te: Rota ~ De 1I:f 11I&t<I1c;¡¡ perf<la.ti SIZE S~ IN'T!RVAl Op\1'Sqz D\'1E 4-6'8- 5 4958 - 5a:I5 0 01)'02102 4-6'-8" 5 !ÐJ.2- !œJ 0 07.l'Q2fC12 4-6'-8" 5 5D95-5-116 0 01J'Q2.'œ 4-5'ð" 5 5167 - 5184 0 07.l'Q2fC12 4-5'8" 5 S235 - 5276 0 07.l'Q2fC12 2-114" IS 16S!i -17:0 0 1Z14M1Z :!-114" e 71&1-1765 0 1Z141Q2 2-1.'4- 5 m4 - 17a1 0 1::!,140'Ð2 :!-114" 5 17ð5 - 7791 0 11i14f112 r: I PSTD H 8194' 17" CSG. 26W, L-eo, 0- 6.276'" H 8279" ~ DI\ -re 09131,'01 05,'2QJ1n 07o'C121D2 0711(¡.o02 07 i31.'1Xl OSI'Ol5Jt12 D\ TE RBI' 8Y CCMJENTS 1207r02 JaM'(( SeTMEfIlA ÆRMT9G M,1CH 12rtoi.Ð2 CAOt'KK AtA!AIS 12i115r02 MiI1<K GLV D\1'!CCJVIE1ION 01.4J40Ð3 ..VKA.K GLV 0'0 04.ClðrÐ3 O~fTP iVDLÐ CO~ REV BY OO~'ENTS CAlGlNAL cor.~ Jar ~S!I) ecwt.emN WAD NT1I\L cx)rJA.~ TMII NT1I\L cx)rJA.~ lJID\ T! .æ!J1(A K G.. V C/O ALtU1 G.. V U:ÐA ~ ) l/1l/05 S*ETY NOTES: GUfS. STA #1 & 12 JIR E 3-112" X 1-112" MMG· WS W\TERFLOOD MANDRELS. 748!J1 7500' 7502' 7505' 752~ 1548' 156CJ1 H 3-1/2" rex NP.ID -2.813·1 H 3·1/2" Xoj-t/2" XO,O· 2.940" I H l' X4-1J2· BIIJ\ $03 ~R. 0- 3.815" I Ii 4-1/r X3-tlr XO,O- 2.92D!" I H 3-1/2'" rex NP.,ID -2.813· I H 3-1,'2" I-ES, XN NP. D- 2'.75' I H 3-1/2'· 'M.S;, 0 . 2.005·~ I 1624' H AATAGI 8O~W H RA TA.GI BOAfiII. LS LNrr Wa.L: L-1D8 P!JIUTNo: 2021090 API NO: 51>D 29-:z3II9:J·1XJ sa; 34. T12N. R11E. 2412' NSL &35118' VÆL BPexploratlon (A1.ka) ) Application for Borealis Area Injection Order Modification ) 1 Ill/OS Exhibit V -4, current schematic of L-I09i TfII!! - 4-1.116" 5M aw wa..LHEAO- H"FM:::SM AI,,; IIJi\ IVft - Nl'A KB. aI!V - 76.4' eJt. I!J:V - 53.6 KCP- 400' MiiX M~e - 36 CI! 4298 CilIUm Me - 1502' CalumTVO .. e&!)It ss !~"8"CSG.40f;, I.-aO.1O -8.75" I-t 2120" ~ Minimum 10 = 2..813"" @ 1260' 3-1/2" HES X NIPPLE L-1 09 I SAFETYNOTES: ~ ~ iOU' 1"1 9-6iS"1'AU I=ORrOOLLAA 1 ~ .----J 5~ ~ ~ I ~ 14-1/2" 1'!G.12.6i\U-ao, .D152Þ:f,.IC-3.9ea" 11 46153" 1---"\ I ~H2-TBG, i.3'fII, L-80'. .DG87r:pt. D - tl92" H PfR'=ORA roM sa",.... RY ftff LOO: ANGI.!ATTOPF!!AF: 36047,64' Ncte: Refer II) PIOl:lœuan œ fOr tlita1c-aI perl' data SIZe SPP' NTEftVAI. cønlSqz CA TE: 4-5.18" S 4164 -479& 0 OSi3DlCQ: 4-5-113" 5 4&44 -4680 0 Q5,'3a.'E:a 4-5.". 5 4894 - .491i0 0 Q5/3DlE:a 4-5~· 5 4952 - 4985 0 Q5iJlh'm 4-5.". 5 5024 - EO&.5 0 OS.'3Q,tlia 4-5.113" 5 5095 - 510ð 0 Q5iJII/ta 2-1.12· 7484- 7514 0 117,'1'6/œ 2-1.12· 1524- 7&54 0 l17i16/D2 Pelt) H n'n 17" CSG, 29. L-&l, BTCoMCD,IC - 5.276- H 1808' DA Tf ÆV BY Ca.fr.£NTS 0&'11102 Q\C'KK ON;N,\L ca&lSlON 1Z3G'02 Q\C'KK GLV COAAS::11CNS O:!m9'03 ~ 1VD COfR!CnON 03t1Q'Q3 8WSlTL~ Aoo ÆR=SFRCN1i'2002 O4fO&'03 [æ¡'TP Ì'VD'M) COIW!:TCNS 7331" I ...--t 2261" 1-14-tl'2" HES XLANDNGNP, 0- 3.813- " --'= GAS I.PT MAlNDJIII!1.S ST MD 1\1'0 Del 1YR! VLV LATCH FORT CATe: 5 3803 34~ 34 KSG-:2: DMf I!IK-S D œMi7.'D'.2 4 4415 3996 36 :tœG-:2: DtM BK-5 D O!itIl1,'D2. 3 4520 4i0!2 35 KSG-:2: DW BK-5 D 09f07/D2 WATER R.OOO MANCfB.S Sf MD 'fVID Del WI='! VLV LATCH I=ORT OAT!' 2: 41694 4223 31 w.G~W our ft( D OSi17,'0:2 ., .1153 4270 31 ,~W DMf ft( D 0!i/111"0:2 . 1---1 4585,1 H4-llr I"ES x fIIP,IO - 3.S13" I 45k" H7" X4-1f.2· aIGUW!MI!ftP!<PlIO-3.a7D" 4653" H4-1,'r )( 3-11,'2" XO. 'Ð - 2.!m. I It--I ~ .----. ---I 1260" H3-1.'2" t-ESX fIIII"ID -2.S13- I 7213" H1" X.4-1.I'2" IIIJR $03 R<~ 0- 1992" .1 7298" H3-112"' t-ES x tIIP,ID - 2.S13" 1319" H3-1i'2:"I"I!SX ",10 -2.813" '--1 7331" H3-1 rr WlEG. D - 2..!Ð!," I 1GO" H1· M\FI<eAJTWlRA TAG I - c,t. TE Rev BY cor.M:NTS 5œ!Al1S Utfl" We.L: L-1D9 Æ!VI.fT Pel: 2O-1201D API h'Þ: s.ø~23:146-QD see 34. T12N, R11 e. 2316' NSL & 3726' VÆL. !II Bcploratlon (AInU) ') Application for Borealis Area'Injection Order Modification ) l/ II/OS Exhibit V -5, current schematic of L-llli 174EE- 4-1116· eM' W!U.H6\O- FM: ACTUA 10Ft - ~ ~. aeI - 16A' tF. a..1::I - :52.02' KOP- eœ' Mix A,ngle - 4D '@ 1595' DmJm PoD - 707S' DltmllVD- 66LV.ss !}.S'S· CSG, Q, L-eo, D - 8.8:!5" H 2922" --A Mininum ()::a 2.81311 @ 6768" 3-1/2" HES X NPPLE 4-tl:z' 1!IG. 12,S"L-eD, .0152 b:f. D -3.958' H 4375" PewOAATION SUMMARY ReF LOG¡ TO' PeRF ÞNGLEAT 'TOP PERF: 10@ 4546' JIbte: Rel!rlD ProdUC'lØi [II t)r hlita1ca1 eet ~a SIZE SPF IN1E:RVAI. OXVSr;z: 0A1E 4-61'~- 50 4'546 - "566 0 œ.I1J4l'02 4-S'8" S ~1 t! - a¡æ¡ 0 D!.1GW2 4-&'a" S 4650 - oUi73 0 D3JDU~ 4-5t'8" S 4119 - 4729 0 D31GW2 4-6'a" 5 4~6 - .œD5 0 D3l041Q2 4-5iS" 5 ~2 - 4iS52 0 œ.i04m2 ~"I"2" 6- 7014-7036 0 03J'22'Ð2 :2-112" 6 70417 -7052 0 03.122/02 :2-11'2" ,6 1070 - 7078 0 D3.iZ21'i12 I 3-11'2' TBG. 9.28, L-eo,DDa7 1:1:'f, Ð - 2.992:· H 6831' I I FeTe H 1505" I r CSG, :ø, L-eo. ID - 6..27!" H 7589" D't:Æ 030"116'02 0)'12,'[)2 0)'16'02 03i22lD2 06'Q6'02 0.w&'D3 PEY 8Y cow.ens ORGM. L CCMREOON OirrP CCfaIECTIOhS ~,., GLV I..PM Te CW$.I1<KACFe¥S R..t1II GLV l.PQt, Tf ~/T'¡:I T'VD.'M) OO~ DATE ÆV8Y L-111 =: I I SAFETY NOTES: GUrS (I: STAt1 & 12 ME 3-112"' X 1-112" MMG-WS, WlICH ARE WATERFLOOD MMDREL5. =--I 97., H 9-5'8" ~MPORTca.LM I I 2266" H 4-112:"I-UX Þ.F.ID -3.813' I . tlAs LIFT,^,~as œv TV FIE VLV LAtCH 3 KaG-2CMY eK-5 8 KBG-2 CMf 8K-! WA f!M.CÒ.) i&.wIdAa.S œv TV PI!: VLV LA Tt:H 8: Þ.Q¡G.W FtKJ!) FtICP ,8, tRtG-W RKBJ RKP FOR.T DATE D 03,1'136'02 D œJ06'02 L ~~T 3:2 :~ 3 4199 3&20 FORT DAT! I) œJ06"02 D œJ'aMl~ ~J J ST &.D lVO :It 4418 4031 1 4478 4097 4308" H 4-1h':z' HIS XNP, ID- a.113" I 4319' U r x 4-1.12.- 8KR PR!M!R PKR. ID - 3..i10' 4377" H 4-11,'2" X 3-112· XO, D -:2:..992' I 3-1.t'2"TfJQ, 9.at, L·e:D, ,Dee? Dp1', D - 2.992" I ': ':---1 5243' H r TAM FOIU COLLAR I 6168" H 3-t,':.!" HES XNP,IO- 2..813"1 6718" H 3-1,'2" X 4-r 112- XO, D - 2.9W ~ ¡ 6180' ~ r X4-1.Q.M Bk1\S-3 PKR.ID -3.675· 6786' H 4-1!,':z' X 3-1.'2· XO, D -2:.9!4T 6806' H HI:.!" HIS XNP~ ID- :U13' I I 6826' H 3-1II:.!" HIS X NP',ID- 2..113' I I , I 6838" H 3-1.':z' WI.£G. D - 2:.9C6'" I I H B.MDTTNOTLOGGI!C I I---i 6892" H r 2f3f x 21)' p\p JTW, PIA TAG I J 7362" H T 2ef X 2D' FIl.P J1"W, RA TAG I (X)Mræn'S 80ÆALS UNT \"ŒLL.: 1.-111 FI!'.MT ~: 2D2D300 AFt ftÐ: 5D-D~2306~OD see 34, T12N. R11 e: 233!l NU. & 3873' wa. IBP ecplOl'aUan (AllSka. ) Application for Borealis Area Injection Order Modification ') 1/1l/05 Exhibit V -6, current schematic of L-115i L-115 1-, 1J;EE .. ....1I't8:" erN \NaUø[)~ AIC "'c I'LlA. rotilI.¡¡; NÂ !1(8. I::U:.Y . '11. l' iBF. 8.£\1'.11 I'Ü ¡iroPa 1~ '!w..: AI'!.. ~ ..... ..sa-l iCIIhm t.l)1II &DU' 1i:IIhftJ. n; 0 ~ o!I1OO'S' - - 'fJ.5Ift"C'Sa. -41», L..:w. CUI &'öS* H 213S' r' M ¡nimum ID = 2.813" II: 7541" 3...112" HES x NIPPLE x I 4-t/1"''T(k), U~.L·;!!Ø..0152::eJ,ll.iCu¡·9.{Q" ~ 4421" I-':JÍ ~ o I '3;..112* Tæ. fI:2II, L·&O,.aœ1 .... to 112, fIIIW" I ; :M:I'2"Tæ.~:.I1.-ao..œë1Itoþt.l)a2..1Xœ H N17 'J PEJ.llFCtiitATK:iN SLHWiiI'i" REF !t..OO: Tel" PSitf' .MroLE ,.., lOP p~ .ü. ~ ~ iA* ~ ~ œ b' !IÎIIIw»ìieIM t*f diIiIïI SQ£ I!:IPF NIER......L Qøu'&al. CATIE ~ ð ~._ a, œ:2On2 ~ ð G't.æ:s Q O~ 4&" !I SCØÞ· 511) ) ~ 4-S..IS" ð 5,132·5141 0. o:r:20112 +&a" ð sa . 5218- Q 00':XID2 4M" ·a S311· 531!!: 0, ~ 2-112" !I 17D1 . j'ß¡ Q IDtMt2 2-Ul' !I 7&14. 1&54 0 ~ 2-'W" .£1 7885 -1&76 Q ~E1D2 I PBm ~ IMET'f HOTEl:: QUI". ITA,'" .. a ARE "''11'2.'" X 1..11Z'" MIIG-W,I, !MIlCH ME wÞV'ERFLOOO MANDRELl. 11111" ~ 'Þ8ar.'Te\lIIIiJlCfUCOL1.JIR I aU' H .....1.tl" tB )OIP, D...~&1-r I - .-J .. ,CP¡iI úfT'~ C6I' TYÆ~'1."· 1.Ä'J'CH 'Ii01T DATE 41 kEIQ-Z r::M; EIK-S ) otJlCi1/fA. 3( 1ŒO-2: [Mr' BK-'Si 0 oe.w.w.:t.l WtlTSiF1.CIOC IIMNDRB.ð: iCE\f TYÆv'LY U.ATQt FOiII DATE .... IiAIQ.'W ftJE) RtIP ) Gœ'.2QIOZ .... IIItC-W fi:iÆ) Rtc:P I) ~ iT '.IiiI) NO .~U20 ':is 424& 3fIII(J iT iWO TVO '2 .so7 .1 14575 3ØI :B)--i I csr H ...1.tl" ttiB )( NP, D ,¡¡S81r I 4ST2' H 1"'X+1.I~ EKRPREMER:P'iiI51:, IO¡¡ :U...'"'5'" I 4t3O" H -4-1(2:" X 8-11'2" XO.ICI II 11im" I - . I 154T -1 ).1/'2" tE!ii X NP, D '* '2 81'!t' I i 15. ., ~1t.l' X .... i.12" XO I I 1$. H rx,....1tl'" Bt<R:5'-j Am. D...·!I.$1S" I I 15SS H .....1.tl" X 8-il'2" x.o. 10-1861" I I 1$. H '). il'2'" tEB X tfP, D ~2ð1 r I I 1CDC" ~ '),11'2" tEB )( NP, D.. ~;!!'1'!i" I 1C18" H ~1tl" fNLED, l)a2!1S'" I H aWl) IT OOT .LOOŒD I ~ 7CBZ' H r"_ X21' IJJPJr~ R:A TAG I ~ 1151" H r* X, 211' PJPJr 1M RA 1...0: I ""1'1' I~ RBI EN CCMiENTS 827D" 1"(':CIQ,-"L.ao œM!a'. -'~8.~r H £IA. IE . iiEv 81' iX'IIIIIWENTS ' , a:r.t)tQ2 OfW1ML œMlE'nON œ.mm2 0f1JõI ~ œ.œtQ2 RlMI GLV CGIiIECTONS 0!It1W2 OItfSnh,.l4.00 PERfS DI!ò07In2 RU*'I GL \l1JDII¡, TE ~ œstTP "1vOMD CORRB::roN9 Qll¡iE E':iICÆAL~ LHT \\QL: 1.-11fi. ÆRMI' No; ~ 1..00 "'!PINe.: ~~S-OO sa:~. T1~. it11E.:1S43:' N8L & !Ø.)t" ML .. _!oration (~lIIbi ) Application for Borealis Area Injection Order Modification ) 11ll/05 Exhibit V -7, current schematic of L-117i 11&" .t-1.ttø- OIN waLI£AC. RWC:" ,Ilo'¡,,;l"',-æ ll- ks. 1i:U:.1I" SF. EæJ ;¡: 1<(Pa. 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T12" m1E 2e01' ta & :Ii·7,f w:L. . .".'1IIiM IAIH"'" ) Application for Borealis Area Injection Order Modification ) 1/11/05 Exhibit V-9, current schematic ofV-lOOi ;H '58" ~TAMPORTCOUAR ~ 2021" t1'" TAIII FOm'CCUÞ.R: I · I 2211' l-r--1t.2:" ~X Nfl, I) II :I.flr 1 t& "I'FEE.c; "-1116"' iSM CIW V8.1J.B.Q.a:: 11" Ail: AC1UA "fCRa tea. B.BI.a:: .... l:Lev' II "\«)p ill \au,... 'b.ur. ~. b.m''/UiII V-100 61' .:11I 3-100' !'i~,O .tß.1a.' 1IN1' e&œ' sI lue cæ.GI, L.ao BiTe¡ DiI US" U 273S' r--A IAFETYHOTEI: Minimum [Ð = .3..72511 .7787' ......-,SG13. ~ MUIŒR Jll'11a., 'IN I¥. TAG I .4-112'1 HES XN N.P'PLE LL 'I¥;JLFr iWANtR!.:S I aTL t.Ð 11\'0 1 UN I1YÆJ '.'1.'" I LATCHJ PCfiiT I r:».TE 1 1 1'5!i1 fl3W 13 r Me1I OM BI{ I CŒiQw.t · I 1m' 1 14-112" HSS X iIIF, D.a 3.-81!" 1 8 g--t 1~' 111' X.4,..1trBIfiPÆNfIKR,iþ<ll~.t1S- 1 , 7cr¡- 1-14-1..a- H:!9 x iIIP, Da 3.9I!" I 7m' Ut.1J2'" H5!B X~. Da 3.at!" 1 1103' U4-1D" lHQ.E0\J'EA&IÐT I 1....117 1I&Q. 1:2'.. 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EQIor.aoft (AIM b) ) Application for Borealis Area Injection Order Modification ) 1/11/05 Exhibit V-13, current schematic ofV-119i '\IìEE~ Y.e.LI-ØOill ,lrC'!IUII.lORJiI lB. aeJ ill EF. a.EY;\¡ tOCfI ;\¡ MlaxAn,-, :¡¡. Cahill Y).a: ·....tarn'I'II'C¡¡¡ ....1/!B·,QM' lAiC N.I. 112.5' a.1' 6OD' 570 fIKIj" 1 [fIBD' ð9m'~ V-119 . I I 9-!1rC83, a:. L-Ø1, Da B.Hi· H $3C' ~ -I MinimumD = 3..125" 810041' 4-1/l" HES XN H,PPLE I It I tAÆTY NcnEI: I 2214" H <11-1I'l"'" xy:¡, I].a; :U1r I i. aASLFTlWillOB.S: aT P.Ð 'NO æJ 1VÆ 'liLY LATCH FCRr Dt."Æ 6 !12:1 :2!5D8 56 1œG-2 D:::IIE BK 18 œtl5iQì1 5 oI!-44 13D7 55 tœQ.2 CiWf BK Ð D4t21h'Col ~ !B02.c!D1 58 tŒÞ3-2 D:::IIE BK 18 œttlS/OIII ! 1..:38 &11M !S.- tœO-2 D::t.E BK 16 DSttISA)! 2' 850a $'13 !W tœG-2 IXf.E Bt( 18 D6I'1!St\'M ~ 11I68 &190 53 tœO-2 æ:. BK :u œttl5it:W I S931~ H ""1'2" H!B X Nfl, Ca UU" I g g---; 9 MIS' H rX04-1œ' BKRPRBIAl:R I t ~ 14-1/2'" "I'BO. 12.-' L.ftD, .,0152 tf'II', D.a. U5I" H toolf I I ÆRFCAA1k'».I st..I.IMR't ¡;ø: 11.0O:, aJ,II¡ D Q.I OIJ 14104. AtnEATTOPFIAF: 52'111D~a' N:>Þt: JW.r~Rcda:tklfI œ for ó!!iIo1Ð1lc:II þIIId¡ttI SIZS·SFF Nt'SNAL CpI/a¡z Q!f,¡1E ):3J,S" ,9 loœt1-. Ur2œ 0 ~ I PB1D H 11::' I~ I rcsa. 291, L.øo. 0-6.2:.'·'e.- H -"" EJ.II,TE FëV 8)' ca.u:NTS GU2-W4 KAle. CMOINAL COtIJILEI'DH O8I1so.t ..L...LIM. K 13.'11 CIO ~ LlJ(l(AK ÆRRi: ~ 1'£ RSf BY UlG21 ~ H 04-11'2" H!B X tIP. Oil 1813" 10041~ H "'112' I-ØI :0.1..... !D ;to.:!.1:M' I 1ooU' H ....112:" w.æ. Dill 3.IM" I t 101C' H r WARœi! J1'" I 1æG1" H :;- "'B<ER JT I OOMIIhTS aaë9:LSUfT WK.L: 'J.'11S ÆRMT Jib: 2D4C0410 API tt'I: !5Ð-112D-2:3'2Dt-OO· see 11. T11N. R111S 4645,1 NBL & 1 aID' \\S.. SPec ¡mfìIØiCI fI (AII1:SiD ~ 6 5 4 - ~ c o :¡:; () f!3 u. .. J: en 'CD 3: 2 Application for Borealis Area Injection Order Modification ~ i I, i \ ~ \r:: , \~,' \\\ \ 1, ; ! ~t .. \ / \~/. Borealis and Kuparuk Oil and Prudhoe MI Compositions I ¡ Component Number Name 1 Nitrogen 2 Carbon Dioxide ~ .'. Hydr,?~e!"! Sulfide 3 Methane 4 Ethane - ---- -- --~ -~ 5 Propane 6 iso-Butane 7 n-B utane 8 iso-Pentane 9 n-Pentane 10 C6 --~ ~ Benzene C7 Toluene C8 C9 ¡----- - ¡ C10 C11 C12 C13 C14 -------¡ C15 - ¡--- C16 C17 C18 C19 C20 C21 C22 C23 C24 C25 C26 C27 C28 C29 C30+ 1/11/05 Exhibit VI-I: - --------- , - Kuparak Carposition ~ Borealis~on_ -- -- - ------------ , ',: 'h-:-- - --~ J .," Å f J ,7, Ft I - / , L:-, -~ ::c... ·,~·1···:-- _ _ - -_ 0".___ ..,.A=c..'".c:. .~: -.:.._>,c~·,,·, -.-- " .",' ..~¡ - - -- --- - -"--... :-~~1-i~!~s=1i-=;-t~: o~:: ~ ~ 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 Z3 24 25 26 27 28 29 30 31 32 33 Con IpOIIeI1t f'brber Miscible Gas (Mole 0/0) 0.1220 19.5280 11 12 13 i 14 l~__ ¡ 15 16 17 18 19 ~~20-----" 21 _~_~~,,~<;.L-o 22 23 24 25 26 27 28 29 30 31 I 32 133 ~ ¡ 34 r ì I I i ! 33.8430 19.6110 23.6210 1 .6680 1 .5860 0.0030 0.0010 0.0080 0.0090 '-' ~ ""'~-- Application for Borealis Area Injection Order Modification 1/ 11/05 Exhibit VI-2: Water Source Well W-400, MPUF-02 Water Compositions Prince Creek Formation Water Sample Analysis Well: Sample Date: Aluminum Barium Bicarbonate Alkalinity (Dissolved) Calcium (Dissolved) Chloride I ron (Dissolved) Fluoride (Dissolved) Magnesium (Dissolved) Manganese (Dissolved) Potassium (Dissolved) Sodium (Dissolved) Sulfate CaC03 - Calcium carbonate mg/L - Milligrams per liter MRL - Method reporting limit NO - Not detected W -400 9/8/2004 0.6 20.8 176 249 3406 0.62 <1 62 0.041 258 1710 75 MPUF-02 6/19/2002 ND 95.6 76.8 1220 0.647 0.159 11.1 ND 3.69 725 ND Units mg/L mg/L mg/L as CaC03 mg/L mg/L mg/L -----' mg/L mg/L mg/L mg/L mg/L --- Application for Borealis Area Injection Order Modification 1/11/05 Exhibit VII -1: Borealis Forecast Production and Injection Inclusive of Water and Miscible Gas Injection Projects - - ----- -- -- Oil Production Water 35,000 90,000 30,000 80,000 - i 25,000 ~ 70,000 6 60,000 - (/) 20,000 ! 50,000 - '-" ! 15,000 40,000 - 1-0 ð ~ 30,000 - 10,000 ~ 20,000 - ---..- Injection 5,000 10,000 - -..- Production 2004 2009 2014 2019 2024 2029 2004 2009 2014 2019 2024 2029 Year Year ----------.. - -. ---- -------- Gas Oil Recovery 60 2000 40% ----- 50 -.- MI Injection 35% - ;E -..- Production -- 1500 ~ 30% - u ª 40 â '-" c:--' --- GOR rFJ ~ 25% - -~-- i¡::¡ '-" t) ~ 30 - 1000 ~ 0 20% - ~ 20 8 & 15% - ~ 0 500 ð 10% - 10 5% - 0 0 0% 2004 2009 2014 2019 2024 2029 2004 2009 2014 2019 2024 2029 Year Year Application for Borealis Area Injection Order Modification 1/ 11/05 Exhibit VII-2: Distribution System for Borealis EOR Miscible Injectant I-Pad (Potential) -..... . : : ~........, .. " ....... . . " . " . . . " . . . . " . " . . . . " " '-- L-Pad MI Pipeline to N-, M- and S-- Pads . GC-2 V-Pad ~ - , EWE Junction Z-Pad . W-Pad Application for Borealis Area Injection Order Modification 1/11/05 1 0.8 0.6 - Oil Recovery, fraction 0.4 ' 0.2 ---' o o Exhibit VII -3: Borealis Minimum Miscibility Pressure (MMP) @ ® -- ----- MMP = 2150 psia - -- - - - - - - - - ~ - - - - ~ - - - - - - - - - ® __J - - - - - - - - - - -- - - - - - - - - - - - - - - ~ - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - - - - - - - - -- - - - - -----------------------~-----------------------------------------------~-------------- 1000 2000 3000 Pressure 4000 --- 5000 Application for Borealis Area Injection Order Modification 1/11/05 Exhibit VII -4: Model Oil Saturations Initial: .~ ~ ear of Miscible Gas WAG Injection.: After 5 years of Miscible Gas WAG Injection: ~j -- Application for Borealis Area Injection Order Modification 1111/05 Exhibit VII-5: EOR Project Production and Injection Forecast 16 60 14 ----- Borealis EaR Oil 50 --.- EaR MI Injection R 12 -c ~ Returned M I ~ c. 40 u .---- 0 10 ~ .c E 30 ~ ... 8 CD CD m 6- m a: 20 a: - tn .- 0 4 as G 2 10 0 0 '~ 2004 2009 2014 2019 2024 2029 ) Application for Borealis Area Injection Order Modification Exhibit VIII -1: Offset Well Integrity Wells within 1,4 mile of Service Well 'C-14 . $.gO ~ . hili ) C) 1r-!:>,>; . ~ 1C-25 \ .~ :c ~~ ~ / ~"'_.>----~// /~~ / \ ~ ~ "'_'_'7_11_11 /"~ . ~/ - \ 1C-12 . Mlt [) Application for Borealis Area Injection Order Modification 1/11/05 Exhibit VIII-2: Offset Well Integrity-Wells within 1,4 mile of Service Well Well Measured Subsea TOC Comments Well Status Well Depth Depth 30% washout Offset Name Name Description Kuparuk Kuparuk (It) MD L- 119i Injector Water Injector 9058 6602 n/a USIT run TOe 6198 L- '--- 118 GL-O Oil well on gas lift 8726 6426 1294 6904 v- 114i Injector Water Injector 11344 6607 n/a USIT TOe 3101 v- 115 GL-O Oil well on gas lift 10053 6632 1067 6430 85 ft fault between wells --"-.""~-,, ( Exhibit IX-2: Borealis Pressure at August, 2004 Field and Model Pressure ) Exhibit IX-2: Borealis Pressure at August, 2004 Field and Model Pressure Data