The URL can be used to link to this page

Home My WebLink AboutDIO 031 e e 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) l.ð D 31 Order File Identifier Organizing (done) o Two-sided 11111111I1111111111 RESCAN J Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NorType: D Poor Quality Originals: o Other: NOTES: Date 7/3/ f) 7 Date 7/3/ f) 7 BY: ~ Project Proofing BY: 8 Scanning Preparation BY: = Date: Production Scanning o Rescan Needed 11111111I1111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: /5/ 1111111111111111111 /5/ + = TOTAL PAGESJ 3d- (Count does not include cover sheet) /5/ 111111111111111111I Stage 1 Page Count from Scanned File: J 33 (Count does include cover sheet) VÝES NO Page Count Matches Number in Scanning Preparation: BY: ~ Date:7/3J07 Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. YES /5/ ìN1 P NO tliP t11P ReScanned BY: Maria Date: Comments about this file: /5/ 1111111111111111111 11111111111111" III /s/ Quality Checked 1111111111111111111 10/6/2005 Orders File Cover Page. doc INDEX DISPOSAL INJECTION ORDER NO. 31 1. March 14, 2007 2. March 20, 2007 3. -------------------- 4. April 30, 2007 5. -------------------- 6. July 1, 2008 7. June 24, 2008 8. July 1, 2009 9. July 1, 2009 10. October 31, 2011 11. October 26, 2012 12. March 11, 2013 13. April 30, 2013 14. October 29, 2013 15. October 20, 2014 16. February 5, 2015 Oooguruk Unit DW-1 and DW-2 Wells Pioneer's application for DIO for Oooguruk Unit Notice of Public Hearing; Affidavits of Publication (Anchorage Daily News and The Arctic Sounder), email distribution, and mailings Email between AOGCC and DNR re: Public Hearing Fracture Report Schematic Pioneer's 2007-2008 Annual Performance Review for DW-I Pioneer's request to increase disposal injection rate (DIO 31.001) Pioneer's 2008-2009 Annual Performance Review for DW-I Pioneer's request to change UIC Annual Report (DIO 31.002) Pioneer's 2010-2011 Annual Performance Review for DW-I Pioneer's 2011-2012 Annual Performance Review for DW-I Letter from Pioneer to AOGCC re: Notification Pursuant to Rule 7 Letter from AOGCC to Pioneer regarding Investigation of Improper Diesel Injection at ODSDW 01-44 Pioneer's 2012-2013 Annual Performance Review for DW-I Caelus' 2013-2014 Annual Performance Review for DW-I Caelus' request to revoke DIO 31 (DIO 31 Revocation) INDEX DISPOSAL INJECTION ORDER NO. 31 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICA nON OF Pioneer Natural Resources Alaska, Inc. for disposal of Class II oil field wastes by underground injection in the Torok Sand in the Oooguruk Unit DW-l and DW-2 Wells, Section 11, T13N, R7E, U.M. ) Disposal Injection Order No. 31 ) ) Oooguruk Unit ) DW-l and DW-2 Wells ) ) ) ) June 19,2007 ) ORDER CLOSING DOCKET BY THE COMMISSION: The Commission has the closed the Docket in the above captioned matter. DATED AND EFFECTIVE at Anchorage, Alaska and this 19th day of June, 2007. BY DIRECTION OF THE COMMISSION nJ- Jody J.jCólo ..' e ! ) SpeCiá'I Assista t toltlie Commission . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICA nON OF Pioneer ) Disposal Injection Order No. 31 Natural Resources Alaska, Inc. for ) disposal of Class II oil field wastes by ) Oooguruk Unit underground injection in the Torok ) DW-l and DW-2 Wells Sand in the Oooguruk Unit DW-l and ) DW-2 Wells, Section 11, T13N, R7E, ) U.M. ) ) June 19,2007 ) IT APPEARING THAT: 1. By application to the Alaska Oil and Gas Conservation Commission ("Commission" or "AOGCC") dated March 14, 2007 and received on March 15, 2007, Pioneer Natural Resources Alaska, Inc. ("Pioneer") requested authorization to allow the underground disposal of oil field waste fluids in a Class II well, as defined in 40 C.F.R. 144.6(b), as revised as of July 1,1998, in the Torok Sand ("Torok") within the Oooguruk Unit. 2. Proposed Oooguruk DW-l well ("DW-l") and substitute Oooguruk DW-2 well ("DW -2") would be drilled from the Oooguruk Drillsite ("ODS") beginning September 2007. 3. Pioneer filed an application for a Class I well permit with the United States Environmental Protection Agency ("EP A") on March 6, 2007 covering the same wells. Pioneer intends the requested Class II disposal injection order to serve as a back-up in the event the Class I well permit is not issued prior to commencement of drilling operations. 4. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on March 25, 2007 and in the Arctic Sounder on March 29, 2007 in accordance with 20 AAC 25.540. 5. The Commission did not receive any protests to the application, comments, or requests for a public hearing. The hearing tentatively scheduled for May 1, 2007 was vacated. Disposal Injection Order 31- Oooguruk DW-l June 19,2007 - Page 2 of8 FINDINGS: 1. Location of Adjacent Wells (20 AAC 25.252(c)(1 )) DW-l is planned as a vertical well located 2,385 feet from the north line and 1172 feet from the east line of Section 11, Township 13N North, Range 7 East, Umiat Meridian. The well will be drilled from the newly constructed ODS located in State of Alaska waters within the Beaufort Sea approximately 5.7 miles northeast of the Colville River Delta. DW-l will support Oooguruk Unit development as the disposal injection well for Class II drilling and production wastes. No wells are located within a If,¡ mile radius of the planned DW-1. A substitute disposal well, DW-2, may be sidetracked from DW-l or drilled from a separate surface location from ODS with a bottomhole location 2,000 feet from DW-l in the Torok. 2. Notification of Operators/Surface Owners (20 AAC 25.252(c)(2) and 20 AAC 25.252( c )(3)) Pioneer is the only operator within a If,¡ mile radius of the proposed disposal well. The sole surface owner within a If,¡ mile radius of DW-l and substitute DW-2 is the State of Alaska. Pioneer contacted the Department of Natural Resources ("DNR") on April 30, 2007. A DNR representative (Temple Davidson) verbally confirmed to Pioneer (John Hellen) on April 30, 2007 that DNR did not require notification and refused Pioneer's offer of the disposal injection order application. 3. Geological Information on Disposal and Confining Zones (20 AAC 25.252(c)(4») Pioneer proposes to conduct disposal into the Albian-aged Torok, which is composed of sandy, marine, base-of-slope fan sediments to be penetrated by DW-1. The proposed disposal zone correlates to the interval between 4,962 feet true vertical depth sub sea ("TVDSS") and 5,229 feet TVDSS (4,999 feet measured depth and 5,226 feet measured depth in the nearby Kalubik No.1 well. In the vicinity ofDW-l and DW-2, the Torok is expected to lie between about 4,950 feet TVDSS and 5,300 TVDSS. Offset well control indicates that the Torok will be approximately 250 feet thick in this area. Within the project area, the Torok consists of thin beds of siltstone and very fine- grained to fine-grained sandstone that are interlaminated with layers of shale and claystone. Conventional and rotary sidewall core data from offset wells Kalubik No. 1 and Ivik No. 1 indicate that the sandstone beds average 21 percent porosity and about 18 millidarcies permeability. A limited number of samples indicate that the siltstone beds average about 18 percent porosity and 3 millidarcies permeability. The Torok injection zone lies within the thick and laterally extensive marine sediments of the Hue Shale zone. An 800-foot thick arresting zone of claystone and siltstone that is capped by a 150-foot claystone layer will provide upper confinement. A 400-foot thick arresting zone of shale and claystone, which is underlain by a dense, Disposal Injection Order 31- Oooguruk DW-l June 19,2007 - Page 3 of8 100-foot thick HRZ shale layer, will provide lower confinement. The prospective Kuparuk and Nuiqsut hydrocarbon reservoirs within the Oooguruk Unit lie beneath the HRZ shale layer. Well and seismic data show no significant faulting in the area. There are no commercial hydrocarbon accumulations in the Torok in or near the proposed disposal area. Oil shows accompanied by heavier gases (butane and pentane) are present in the Torok within the Kalubik No.1 and Ivik No.1 wells. However, mud-logging geologists rated the quality of the oil shows as poor in Ivik No.1 and fair to good in Kalubik No.1, which is located up-dip. A 12.5-hour test of the Torok in Kalubik No.1 yielded rates of only about 10 barrels of oil per day and 280 barrels of water per day. 4. Evaluation of Confining Zones (20 AAC 25.252(c)(9») The potential to fracture through the confining lithologies at DW-1 was modeled by a Pioneer consultant. The goal of the evaluation was to predict fracture growth during slurry injection. Thirty-two cases were modeled, including different combinations of slurry densities, injection rates, perforations, and fracture geometry. Extreme operating conditions were included in model runs to generate operating condition sensitivities. Pioneer's modeling indicates that the arresting zone would not be penetrated as a result of disposal injection in DW-l. Anticipating batch-type injection, Pioneer's model results expect a radial type disposal domain to develop around DW-1 as injection proceeds. 5. Standard Laboratory Water Analysis of the Disposal Zone (20 AAC 25.252(c)(10») Laboratory analyses of water produced during testing of the Torok in offset well Kalubik No. 1 averaged 24,300 mg/l of total dissolved solids. Pioneer reports that water salinities calculated for the Torok disposal interval using log data from 10 wells within 6 miles of DW -1 range from 17,000 mg/l to 24,000 mg/l. These calculations were confirmed by the Commission for the three offset wells closest to DW-1 using techniques recommended in EP A guidance document "Survey of Methods to Determine Total Dissolved Solids Concentrations" (KEDA Project No. 30-956). 6. Well Logs (20 AAC 25.252(c)(5) Pioneer plans to drill DW-1 beginning in September 2007. Well logs must be submitted within 30 days of well completion. Log data from offset wells to DW-1 are on file with the Commission. DW-2 will be drilled if mechanical problems are encountered with DW-l. 7. Demonstration of Mechanical Integrity and Disposal Zone Isolation (20 AAC 25.252 (c)(6)) Disposal Injection Order 31- Oooguruk DW-1 June 19, 2007 - Page 4 of8 D W -1 will be a vertically drilled disposal well consisting of the following: conductor pipe driven to refusal (approximately 100 feet TVDSS), surface casing set at 2,570 feet TVDSS, and production casing installed at 5,300 feet TVDSS. The surface casing will be cemented from shoe depth to the surface. Production casing will be cemented from total depth to 3,540 feet TVDSS, which is approximately 500 feet above the top of the upper confining zone. If required, DW-2 will be drilled as a sidetrack ofDW-1 (with the same surface location) with a bottomhole location about 2,000 feet east of DW-l. Pioneer may drill DW-2 from a new surface location if mechanical or other problems prevent the use of DW -1 for a sidetrack. Pioneer plans to evaluate the surface and production casing annuli with cement bond logs to confirm that there is adequate cement sheath to isolate the injected fluids to the well bore and intended injection zone. DW-1 and substitute DW-2 will be equipped with tubing and packer to isolate pressure to the disposal interval. Casing, tubing and packer integrity will be confirmed with pressure tests before injection commences in the well and annually thereafter. Oxygen activation logs or temperature surveys will be used during subsequent years while the disposal well remains in service to confirm the waste materials injected are confined to the Torok. 8. Disposal Fluid Type, Source, Volume and Compatibility with Disposal Zone (20 AAC 25.252(c)(7)) DW -1 will serve as the primary waste disposal well for non-hazardous ODS oil field wastes. Development drilling is expected to take three years to complete; during that time, Pioneer will inject an estimated 500,000 barrels of drill cuttings, mud and flush water. Injection during producing years will include well workover fluids, produced water, wastes from any additional drilling, and other fluids eligible for injection into a Class II disposal well. The total estimated volume of Class II wastes to be injected for disposal over the life of the project is less than 1,000,000 barrels. Disposal injection is expected to be made in batches of approximately 1,000 barrels and at rates of about 2.5 barrels per minute. Fracture modeling evaluated the effect of injection rates of up to 4 barrels per minute, injected batch volumes of up to 2,500 barrels, and fluid densities of up to 10.1 pounds per gallon. No formation fluid samples or core analyses from the Torok at the Oooguruk Unit have been or will be analyzed for compatibility with disposal injection fluids. Pioneer states that data and extensive operational experience involving similar waste materials, formations, and depths and much higher volumes and rates on the North Slope provide an adequate analogy for the proposed Oooguruk Unit disposal injection. 9. Estimated Injection Pressure (20 AAC 25.252(c)(8)) Pioneer estimates that the average surface injection pressure will be between 1,800 psig and 2,300 psig. The maximum surface injection pressure is projected to be 3,500 pSlg. Disposal Injection Order 31- Oooguruk DW-l June 19,2007 - Page 5 of8 10. Aquifer Exemption (20 AAC 25.252(c)(11 ) Pioneer requested an EP A ruling concerning aquifers beneath the ODS as part of the underground injection control program Class I permit application process. By letter (dated August 18, 2006), EPA concluded that a "No USDW [i.e., underground sources of drinking water]" ruling applies to the area within a 12 mile radius from the center ofDW-1 and substitute DW-2. 11. Mechanical Condition of Wells Penetrating the Disposal Zone Within Y4 Mile ofDW- 1 (20 AAC 25.252(c)(12)) There are no wells penetrating the Torok within a Y4-mile radius of DW-1 and substitute DW-2. A few of the development wells planned to be drilled to produce from the Kuparuk formation within the Oooguruk Unit are expected to penetrate the Torok within a 12-mile radius of DW-1 and substitute DW-2; those wells will be designed to ensure that no communication path is established for the migration of fluids injected into the Torok. CONCLUSIONS: 1. The application requirements and conditions for approval of an underground disposal application in 20 AAC 25.252 have been met. 2. The Torok disposal zone is about 250 feet thick, and it lies within the thick and laterally extensive marine Hue Shale zone. Upper confinement will be provided by about 950 feet of claystone and siltstone, and lower confinement will be provided by 500 feet of shale and claystone. There are no significant faults in the vicinity of the proposed operations. Disposal operations in DW-1 and substitute DW-2 will not impact production because the Kuparuk and Nuiqsut reservoirs lie beneath the HRZ shale layer. 3. The total dissolved solids content of the water within the Torok exceeds 10,000 mg/l. There are no commercial oil or gas accumulations in the Torok within the project area. 4. For disposal operations, fluid compatibility in the Torok is not an issue. Operating experience and data from disposal injection-involving (i) similar materials and (ii) performance parameters (i.e., pressures, rates, and volumes) exceeding those planned for DW-1 and DW-2-elsewhere on the North Slope provide an analogy for underground disposal within the Oooguruk Unit. 5. The proposed well designs (including casing, cement, tubing and packer) for DW-1 and substitute DW-2 will protect freshwater by isolating injected fluids and pressure to the well bore and intended injection zone. Verification of final well construction Disposal Injection Order 31- Oooguruk DW-l June 19,2007 - Page 6 of8 through cement evaluation and mechanical integrity testing will be necessary prior to injection. 6. Based on the modeled injection rates, volumes, fluid densities, and pressures that exceeded the expected operating conditions, reasonable grounds exist to conclude that waste fluids should be contained within the receiving intervals by the confining lithologies within the Torok, cement isolation of the well bore and operating conditions. Batch injection will likely result in the development of a radial-type disposal domain, limiting the lateral and vertical propagation of the fractures that result from the slurry injection. Modeling predicted a zone of influence (waste plume area) for injected materials to occupy a fracture domain extending approximately 900 feet from the well. 7. Disposal injection operations in DW-1 and substitute DW-2 will be conducted at rates and pressures below those estimated to fracture through the confining zones. Therefore, oil field wastes injected into DW-1 and substitute DW-2 will be confined to the isolated Torok. 8. Supplemental mechanical integrity demonstrations and the surveillance of injection operations-including temperature surveys, monitoring of injection performance (i.e., pressures and rates), and analysis of the data for indications of anomalous events- are appropriate to ensure that waste fluids remain within the disposal interval. NOW, THEREFORE, IT IS ORDERED THAT disposal injection be authorized into the Torok Formation within the Oooguruk Unit subject to each of the following: RULE 1: Injection Strata for Disposal The underground disposal of Class II well oil field waste fluids is permitted into the Torok within DW-1 and substitute DW-2 in the interval that correlates with the interval between 4,962 feet TVDSS and 5,229 feet TVDSS in the Kalubik No. 1 well. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined by the upper or lower confining zones: i. e., confined within the injection zone and between the upper and lower arresting zones estimated to be between 4,131 feet TVDSS and 5,762 feet TVDSS in DW-1 and substitute DW-2. RULE 2: Fluids This authorization is limited to Class II waste fluids generated during drilling, production and workover operations. RULE 3: Injection Rate and Pressure Disposal injection is authorized at (a) rates that do not exceed 4 barrels per minute and (b) surface pressures that do not exceed 3,500 psig. RULE 4: Demonstration of Mechanical Intee:ritv Disposal Injection Order 3. Oooguruk DW-l June 19,2007 . Page 7 of8 The mechanical integrity of DW-1 and substitute DW-2 must be demonstrated before injection begins and before returning the well to service following a workover affecting mechanical integrity. A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in DW-1 and substitute DW-2, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent mechanical integrity tests must be performed at least once every two years. The Commission must be notified at least 48 hours in advance of each such test to enable a representative to witness the test. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1,500 psi, or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. A written record of the results of all mechanical integrity tests must be readily available for Commission inspection. RULE 5: Well Inte2ritv Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by the injection rate, an operating pressure observation, a test, a survey, a log, or any other evidence, the operator shall notify the Commission by the next business day and submit a plan of corrective action on Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. RULE 6: Surveillance The operator shall run a baseline temperature log and perform a baseline step rate test prior to initial injection. A subsequent temperature log must be run one month after injection begins, to delineate the receiving zone of the injected fluids. Surface pressures and rates must be monitored continuously during injection for any indications of fracture height growth. Results of daily wellhead pressure observations in DW -1 and substitute DW -2 must be documented and available to the Commission upon request. Subsequent temperature surveys or other surveillance logging (e.g., oxygen activation and acoustic) will be based on the results of the initial and follow-up temperature surveys and injection performance monitoring data. A report evaluating the performance of the disposal operation must be submitted to the Commission by July 1 of each year. The report shall include data sufficient to characterize the disposal operation and include, for example: pressures (daily average, maximum and minimum); fluid volumes injected (disposal and clean fluid sweeps); injection rates; an assessment of fracture geometry; a description of any anomalous injection results; and a calculated zone of influence for the injection fluids. Disposal Injection Order 3. Oooguruk DW-l June 19,2007 - Page 8 of8 RULE 7: Notification of Improper Class II Iniection The operator must immediately notify the Commission if it learns of any improper Class II injection. Notification requirements of any other State or Federal agency remain the operator's responsibility. RULE 8: Administrative Action Unless notice and public hearing are otherwise required, the Commission may administratively waive or amend any rule stated above 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 fluid movement outside of the authorized injection zone. RULE 9: Conditions It is a condition of this authorization that operations be conducted in accordance with the rules set out in this order, with AS 31.05, and (unless specifically superseded by Commission order) with 20 AAC 25. Failure to comply with an applicable provision of AS 31.05, 20 AAC 25, or these rules may result in the suspension or revocation of this authorization. DONE at Anchorage, Alaska, and dated Ju Daniel T. Seamount, Jr., Commissioner AS 31.05.080 provides that within 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 lO-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., 10th day after the application for rehearing was filed). 01031 Oooguruk Unit - - Subject: DIO 31 Oooguruk Unit From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 20 Jun 200707:53:11 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletI@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, trmjrl <trmjrl @aol.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Do ly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocop ips.com>, Bob <bob@in1etkeeper Dave Roby <dave Joby@admin.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 J. Jones" <JonesD6@BP.com>, "s R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <k ws .org>, Gordon Pospisil <Pospis P.com>, "Francis S. Sommer" <SommerFS@BP.com>, Ml el Schultz <Mikel. Schultz .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@exxonmobil.com>, Mark Kovac <yesno1@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, eyancy <eyancy@seal-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@alaskadc.org>, tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm <mkm 7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens orapower.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@forestoil.com>, Sharmaine 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>, 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 <J erry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Karl Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Gary Rogers <garyJogers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <klyons@otsintl.com>, Steve Lambert <sa1ambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough <admin@aleutianseast.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>, 10f2 6/20/2007 7:54 AM DIO 31 Oooguruk Unit . . Keith Wiles <kwiles@marathonoi1.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@exxonmobi1.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve_moothart@dnr.state.ak.us>, Anna Raff <anna.raff@dowjones.com>, Cliff Posey <cliff@posey.org>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson < le_davidson@dnr.state.ak.us>, Waiter Featherly <WFeatherly@PattonBoggs.com>, Tricia Wag er <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 Wine garner <jimwinegarner@brooksrangepetro.com>, Matt Rader <matt_rader@dnr.state.ak.us>, carol smyth <caro1.smyth@shel1.com>, Arthur C Saltmarsh <art_saItmarsh@admin.state.ak.us>, Chris Gay <cdgay@marathonoi1.com>, foms@mtaonline.net, Rudy Brueggeman <rudy.brueggemann@internationa1.gc.ca>, Cary Carrigan <cary@kfqd.com>, Sonja Frankllin <sfranklin6@bloomberg.net>, Mike Bill <Michae1.Bill@bp.com>, Waiter Quay <WQuay@chevron.com>, "Alan Birnbaum <\"\"Alan J Birnbaum \">" <alan _ birnbaum \"@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 <iody colombie(â!admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/pdf rdio31.pdf . Content-Encodmg: base64 20f2 6/20/20077:54 AM . 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 Westheimer, 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 \~u ~ø ~ (~p\6l THE STATE "'ALASKA GOVERNOR BILL WALKER Alaska Oil and Gas Conservation Commission DISPOSAL INJECTION ORDER NO. 31 REVOCATION Mr. John Hellen HSE Manager Caelus Energy Alaska, LLC 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 Re: Docket No: DIO-15-001 Request to Rescind Disposal Injection Order (DIO) 31 Oooguruk Unit (OU) ODSDW 01-44 (PTD 2071400) Oooguruk Field Oooguruk Undefined Waste Disposal Pool Dear Mr. Hellen: 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov By letter dated February 9, 2015, Caelus Energy Alaska, LLC (Caelus) requested revocation of Disposal Injection Order 31. In accordance with 20 AAC 25.252 (a), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Caelus' request to revoke the DIO. On June 19, 2007 the AOGCC issued DIO 31 approving Class II underground disposal of oil field wastes in wells designated as DW-1 and DW-2. DIO 31 stated an application for a Class I well permit with the United States Environmental Protection Agency (EPA) had been filed. This permit was subsequently issued by EPA as AK- 1I009-A. DIO 31 is no longer necessary to the operation of ODSDW 01-44 and is hereby REVOKED. Injection into ODSDW 0 1 -44 will be governed by provisions of 20 AAC 25 and EPA Class I permit AK- I1009-A. DONE at Anchorage, Alaska and dated February 25, 2015. Daniel T. Seamount, Jr. Commissioner cc: Thor Cutler, US EPA Phoebe Brooks, AOGCC Michael Gallagher Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL, order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh, Angela K (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, February 25, 2015 3:42 PM To: Bender, Makana K (DOA); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha J (DOA); Colombie, Jody J (DOA); Davies, Stephen F (DOA); Eaton, Loraine E (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Gallagher, Mike (DOA); Guhl, Meredith D (DOA); Hunt, Jennifer L (DOA); Kair, Michael N (DOA); Loepp, Victoria T (DOA); Mumm, Joseph (DOA sponsored); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, lames B (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Singh, Angela K (DOA); Wallace, Chris D (DOA) Subject: FW: DIO 31 revocation (ODSDW 01-44) Caelus Energy Alaska LLC Attachments: dio31 revocation.pdf From: Colombie, Jody J (DOA) Sent: Wednesday, February 25, 2015 1:09 PM To: aogcc.inspectors@alaska.gov; 'AKDCWellIntegrityCoordinator; 'Alexander Bridge'; 'Allen Huckabay'; 'Andrew VanderJack'; Anna Raff; 'Barbara F Fullmer'; bbritch; Becky Bohrer; Bill Walker; Bob; 'Brian Havelock'; Burdick, John D (DNR); Carrie Wong; Cliff Posey; Cocklan-Vendl, Mary E; Colleen Miller; Crandall, Krissell; 'D Lawrence'; 'Dave Harbour'; David Boelens; 'David Duffy'; David Goade; David House; 'David McCaleb'; David Steingreaber; 'David Tetta'; 'Davide Simeone'; 'ddonkel@cfl.rr.com'; 'Dean Gallegos'; Delbridge, Rena E (LAS); 'Donna Ambruz'; 'Ed Jones'; Elowe, Kristin; Evans, John R (LDZX); 'Francis S. Sommer'; 'Frank Molli'; 'Gary Oskolkosf; 'George Pollock; ghammons; 'Gordon Pospisil'; 'Greg Duggin'; 'Gregg Nady'; gspfoff, 'Jacki Rose'; Jdarlington (iarlington(&gmail.com); 'Jeanne McPherren'; Jennifer Williams; 'Jerry Hodgden'; 'Jerry McCutcheon'; Jessica Solnick; 'Jim Watt; Jim White; 'Joe Lastufka'; 'Joe Nicks'; John Adams; 'John Easton'; Jon Goltz; 'Juanita Lovett; 'Judy Stanek; Julie Houle; 'Julie Little'; Karl Moriarty; Keith Wiles; Kelly Sperback; Laura Silliphant (laura.gregersen@alaska.gov); Leslie Smith; Lisa Parker; Louisiana Cutler; 'Luke Keller; 'Marc Kovak'; Mark Dalton; Mark Hanley (mark. hanlgy(danadarko.com); 'Mark Landt'; 'Mark Wedman'; Marquerite kremer (meg.kremer(&alaska.gov); Michael Duncan; 'Michael Moora; Mike Bill; Mike Mason; Mikel Schultz; 'MJ Loveland'; mjnelson; mkm7200; Morones, Mark P (DNR); nelson; 'Nichole Saunders'; Nick W. Glover; Nikki Martin; 'NSK Problem Well Supv'; 'Oliver Sternicki'; 'Patty Alfaro'; 'Paul Craig'; 'Paul Decker (paul.decker@alaska.gov)'; 'Paul Mazzolini'; Pike, Kevin W (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'Renan Yanish'; 'Robert Brelsford'; 'Ryan Tunseth'; 'Sara Leverette'; 'Scott Griffith'; 'Shannon Donnelly'; Sharmaine Copeland; 'Sharon Yarawsky'; Shellenbaum, Diane P (DNR); Smart Energy Universe; Smith, Kyle S (DNR); 'Sondra Stewman'; 'Stephanie Klemmer'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Suzanne Gibson'; Tamera Sheffield'; Tania Ramos'; Ted Kramer'; Temple Davidson'; Terence Dalton; Teresa Imm'; Thor Cutler; 'Tim Mayers'; Todd Durkee; Tony Hopfinger'; 'trmjri'; Tyler Senden'; 'Vicki Irwin'; Vinnie Catalano; 'Walter Featherly'; 'Yereth Rosen'; 'Aaron Gluzman'; 'Aaron Sorrell'; Ajibola Adeyeye; Alan Dennis; Andrew Cater; Anne Hillman; Bajsarowicz, Caroline J; 'Bruce Williams'; Bruno, Jeff J (DNR); Casey Sullivan; 'Donna Vukich'; Eric Lidji; Erik Opstad; 'Gary Orr'; 'Graham Smith'; 'Greg Mattson'; Hak Dickenson; Heusser, Heather A (DNR); Holly Pearen; 'James Rodgers'; 'Jason Bergerson'; Jennifer Starck; 'Jill McLeod'; 'Jim Magill'; Joe Longo; John Martineck; Josh Kindred; Kenneth Luckey; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; 'Marie Steele'; Matt Armstrong; 'Matt Gill'; 'Mike Franger'; Morgan, Kirk A (DNR); Pat Galvin; 'Patricia Bettis'; Peter Contreras; Richard Garrard; Richmond, Diane M; Robert Province; 'Ryan Daniel'; 'Sandra Lemke'; 'Scott Pexton'; Shaun Peterson; 'Susan Pollard'; Talib Syed; Todd, Richard J (LAW); Tostevin, Breck C (LAW); 'Wayne Wooster'; 'William Hutto'; 'William Van Dyke' Subject: DIO 31 revocation (ODSDW 01-44) Caelus Energy Alaska LLC James Gibbs Jack Hakkila Bernie Karl KBcK Recycling Inc. Post Office Box 1597 Post Office Box 190083 Post Office Box 58055 Soldotna, AK 99669 Anchorage, AK 99519 Fairbanks, AK 99711 Gordon Severson Penny Vadla George Vaught, Jr. 3201 Westmar Cir. 399 W. Riverview Ave. Post Office Box 13557 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714 Denver, CO 80201-3557 Mr. John Hellen Richard Wagner Darwin Waldsmith HSE Manager Post Office Box 60868 Post Office Box 39309 Caelus Energy Alaska, LLC Fairbanks, AK 99706 Ninilchik, AK 99639 3700 Centerpoint Dr., Ste. 500 Anchorage, AK 99503 Thor Cutler US EPA Region 10 1200 Sixth Ave., Ste. 900 OCE-082 Seattle, WA 98101 �'Qhc�2c� 2St 2�15 Angela K. Singh • • ,.___ :a ~ ~ ~~ ~~_, ~~ ~;. ~a~ s ~ ~~ ~ ~ ~ ~ SARAH PALIN, GOVERNOR tait[1-7~A OIL A~D ~ 333 W. 7th AVENUE, SUITE 100 COI~SER~ATIOAT COMl-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL DIO 31,001 Mr. J.D. "Joey" Hall Operations Manager Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 RE: Increased Disposal Injection Rate Oooguruk Undefined Water Disposal Pool Dear Mr. Hall: In accordance with Rule 8 of Disposal Injection Order (DIO) 31.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants Pioneer Natural Resources Alaska Inc. (Pioneer)'s request for approval to increase the disposal injection rate to 6 barrels per minute BPM) into the Oooguruk Undefined Water Disposal Pool. Disposal injection into the Torok Sand ("Torok") within the Oooguruk Unit was authorized by DIO 31 effective June 19, 2007. Injection commenced February 2008 in support of drilling activities located at the Oooguruk Drillsite. To date, approximately 146,000 barrels of waste fluids have been injected into the Torok using Well ODSDW-1. Pioneer provided the Commission with supplemental simulation data that predicts fracture geometry resulting from slurry injection above DIO 31 authorized limits (i.e., above 4 BPM injection rate and 3,500 psig surface pressure). Modeling was performed using an injection rate of 6 BPM in conjunction with slurry densities of 12.5 and 14 pounds per gallon ("ppg"). As with the original simulation performed, discrete receiving zones within the Torok were modeled to generate fracture geometry in response to slurry injection. Resulting information from the supplemental fracture slurry injection simulation trials show increased length, height, and width of propagated fractures can be expected with increased rate and slurry density compared to modeling results generated with the original DIO application (lower rates and slurry density). Modeling indicates that the zone of influence (waste plume) for injected materials will continue to be confined as intended to the Torok. The Commission finds that the conclusions of DIO 31 remain valid. Injection of wastes into the Torok at rates up to 6 BPM and slurry densities up to 14 ppg will not promote waste, will not jeopardize correlative rights, and will not result in fluid movement outside of the authorized injection zone. Rule 3 is revised to read: DIO 31.001 • • July 29, 2008 Page 2 of 2 Rule 3: Infection Rate and Pressure Disposal injection is authorized at (a) rates that do not exceed 6 barrels per minute, (b) slurry densities that do not exceed 14 pounds per gallon, and (c) surface pressures that do not exceed 3,500 psig. DONE at Anchorage, Alaska and dated July 2 Daniel T. Seamount, Jr. Chairman RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Js { w ~ ~ r V ;,' r (._ x +yI } ~ ;?~! n f k pia" , . l:ommissloner Page 1 of 1 • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, July 31, 2008 10:00 AM Subject: Correction Attachments: aio2b-035.pdf BCC:'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff ; Maurizio Grandi; P Bates; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'Aleutians East Borough'; 'Anna Raff ; Arion, Teri A (DNR); 'Arthur Copoulos ; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; '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'; keelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; 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 McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments: aio2b-03 5 .pdf; Attached is the corrected file name. Please disregard the file named A1010B-035 as it should have been named A102B-035. Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/31 /2008 Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Thursday, July 31, 2008 7:41 AM Subject: Various Administrative Approvals Attachments: co477-007 and aio10b-007.pdf; dio31-001.pdf; aio5-014.pdf; aio10b-035.pdf BCC:'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff; Maurizio Grandi; P Bates; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol Smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin ; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; '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; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; 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 McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman ; 'Rudy Brueggeman ; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:co477-007 and aiolOb-007.pdf;dio31-OO1.pdf;aio5-014.pdf;aiolOb-035.pdf; Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/31/2008 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, ID 83702 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 • David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 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 r 1 l~J Cindi Walker 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 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 `I a, /P~' 7/~/a' • • ~ a d d SARAH PALIN, GOVERNOR D ~ss~ ~~1I L~l`D G S 333 W. 7thAVENUE, SUITE 100 CO1~T5ERQATI011Z' CO1rII~II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL NO. DIO 31.002 Re: The application of Pioneer Natural Resources Alaska, Inc. for the modification of the annual reporting period for Oooguruk Field Development Project waste disposal well DW- 1 and substitute DW-2 Mr. J. D. Hall Operations Manager Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Dear Mr. Hall: Pioneer Natural Resources Alaska, Inc. (Pioneer) reyuests an administrative modification to Rule 6 of Disposal Injection Order (DIO) 31. The specific request described in an electronic mail message dated July 2, 2009 is to revise the annual reporting period for the Oooguruk Field Development Project waste disposal performance report to coincide with annual reports required by Environmental Protection Agency (EPA) and Alaska Department of Environmental Conservation (ADEC). Both EPA and ADEC establish a reporting period of October through September, with reports due not later than October 31. Pioneer states that a majority of the information provided to the Commission is identical to that provided to the other agencies. Pioneer's request is approved. The annual waste disposal injection performance report for the Oooguruk Field Development shall be provided to the Commission based in the following revised schedule: Report Year Re ort Period Report Due Date 2010 July 1, 2009, through October 31, 2010 Se tember 30, 2010 Subsequent Years October 1 through On or before October 31 of Se tember 30 the re ort year ~ONE at Anchorage, Alaska and dated July 24, 2009. ~~~ Daniel T. S amount, Jr. Cathy P. Foerster Chai~ Comm ssioner • • RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days afrer the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default afrer which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on Uie next day that does not fall on a weekend or state holiday. • • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Monday, July 27, 2009 2:31 PM Subject: Public Notice Falls Creek #5 and Admin Approval DI031-002 Attachments: dio31-002.pdf; Public Notice Falis Creek #5.pdf ~ '~`~* dio31-002.pdf (673 Public Notice Falls KB) Creek #5.p... B :'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Frederic Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff ; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve ViranY; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); 'Anna Raff ; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Charles O'Donnell'; Chris Gay; 'Cliff Posey'; 'Dan Bross'; 'dapa ;'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; Decker, Paul L(DNR}; 'doug_schultze ;'Eric Lidji ;'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; 'jah'; 'Janet D. Platt'; 'jejones'; 'Jerry Brady'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; 'Jon Goltz'; Joseph Darrigo; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Elowe'; 'Laura Silliphant'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; Melanie Brown; 'Michael Nelson'; 'Mike Bill'; 'Mike Jacobs'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Winslow'; Pierce, Sandra M(JPO); Rader, Matthew W(DNR); Raj Nanvaan; 'Randall Kanady'; 'Randy L. Skillern'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; Teresa Imm; 'Terrie Hubble'; Thompson, Nan G(DNR); 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjr1'; Von Gemmingen, Scott E(DOR); 'Walter Featherly'; Walter Quay; Aubert, Winton G(DOA); Birnbaum, Alan J (LAW); Crisp, John H(DOA); Darlene Ramirez; Davies, Stephen F(DOA); Fleckenstein, Robert J(DOA); Foerster, Catherine P(DOA); Grimaldi, Louis R(DOA); Johnson, Elaine M(DOA); Jones, Jeffery B(DOA); Laasch, Linda K(DOA); Mahnken, Christine R(DOA); Maunder, Thomas E(DOA); Mclver, Bren (DOA); McMains, Stephen E(DOA); Noble, Robert C(DOA); Norman, John K(DOA); Okland, Howard D(DOA); Paladijczuk, Tracie L(DOA); Pasqual, Maria (DOA); Regg, James B(DOA); Roby, David S(DOA); Saltmarsh, Arthur C(DOA); Scheve, Charles M(DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA) Jody J. Colombie Specia! Assistant A/aska Oi! and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) ~ • 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 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 a~~~/~ ~~~ ~ ~ 16 Wallace, Chris D (DOA) From: John Hellen <John.Hellen@caelusenergy.com> Sent: Monday, February 09, 2015 2:11 PM To: Wallace, Chris D (DOA) Cc: Mike Martin; Andy Bond Subject: RE: Potential pumping operation on disposal well Chris, Thanks for your time on Friday. After discussing it internally and checking in with Thor Cutler, we agree that there's no need to maintain the DIO for the Oooguruk disposal well (ODSDW 01-44). Please consider this our formal request to rescind DIO 31. Let me know if you need anything else or have any questions. John Hellen HSE Manager Caelus Energy Alaska, LLC 3700 Centerpoint Dr, Ste 500 1 Anchorage, AK 99503 Direct: 907.343.2102 1 Cell 907.575.9955 iohn.hellencaelusenergy com From: Wallace, Chris D (DOA)[rnailto:chris.wallace@alaska.gov] Sent: Thursday, February 05, 2015 11:49 AM To: Mike Martin; Schwartz, Guy L (DOA) Cc: Andy Bond Subject: RE: Potential pumping operation on disposal well Mike, Can you please confirm we are talking about this well PTD 2071400? frmWellFilterSub API WELL PTD # Conf UICPermit# Oper Name Well Name Status Status Dt Field Geol.True Sales Ai Sec Twp N/S Rng /E PM Area DTD VD Cd. G CAELUS 000GURUK'WDSP1 1/27/2008 OOOGURUK 11 13 N 7 E U 973 6600 6600 57 50- 2071400 No 2071400 703- NATURAL UNIT 20556- RESOURCES ODSDW 01- 00-00 ALASKA, LLC 44 We have this as a Class I well in our database and so potentially DIO 31.000 and therefore DIO 31 and therefore DIO 31.001 may need to be rescinded if this is in fact a Class I permitted well? We would need to hear your opinion of Class I vs. Class II because the dual permitting is a bit of an issue. We would need to be in alliance with the Class I permit and have that agreement from EPA. My first thoughts are: 1. We would need to do the actual work via a sundry application for hydraulic fracturing. That sundry would need to satisfy the 20 AAC 25.283 requirements including modeling of fracture height and width etc, and anticipated pump rates and pressures (surface and downhole). 2. Once modeling is complete we can look at the DIO for comparison. Hydraulic fracturing / stimulation is not a Class 11 injection or authorized via the Underground Injection Control program (Unless you are fracturing using a diesel based fluid). If the stimulation modeling shows the fractures do not initiate or propagate fractures through the confining zones — we do not need to adjust or review the DIO. If you wish to continue the modeling with the newly created fractures — you may find the model shows the rate and pressure in the DIO could be adjusted up long term — and after a step rate test or TIO plots we could adjust the DIO permanently for a higher rate and pressure via a new DIO 31.002 Admin Approval (and therefore cancel DIO 31.001). We would need to better understand how sensitive your model is for short term pumping vs. long term disposal, or what sensitivities the fluid densities would have. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7ch Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wal lace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Mike Martin[ma iIto: Mike.Martin Cnbcaelusenergy.com] Sent: Thursday, February 05, 2015 10:52 AM To: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Cc: Andy Bond Subject: Potential pumping operation on disposal well Guy, Chris, Looking for your opinion on a potential operation at Oooguruk this winter. We are considering pumping a breakdown on the disposal well ODSN-44 (designated DW-1 in the disposal order). Currently the AOGCC disposal order allows us to pump at rates of 6 bpm or maximum pressure of 3500. We would like to take the pressure up to 4500 — 5000 psi for a short duration pumping operation in order to hopefully clean up (reduce skin, create multiple fractures) the injection zone. Currently we are injecting at —5.7 bpm between 2000 and 3000 psi. Assuming we want to go forward with this operation what course of action do you recommend, apply for a variance? I've attached the initial disposal order as well as the approval for a rate increase. Thanks Mike Martin Caelus Energy Alaska Office: 907-343-2173 Cell: 907-690-0120 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 15 CC� CAELUS Energy Alaska Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, Alaska 99503 RECEIVEDTel: (907) 277-2700 Fax: (907) 343-2190 October 20, 2014 0 C T 24 2014 A®GGC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2013-2014 Annual Performance Review for Oooguruk Unit DW-1 Dear Commissioner Foerster: Caelus Natural Resources Alaska, LLC (Caelus) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW-1), in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) Disposal Injection Order No 31, Rule 6. This rule states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by November 1 of each year and include the following data sufficient to characterize the disposal operation: • Injection pressures and rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Caelus (formerly Pioneer Natural Resources Alaska, Inc.) began injection operations on DW-1 on February 25, 2008. Continuous monitoring devices are in place for recording injection pressures, injection rates, temperatures, and inner annulus pressures. These data are captured electronically, summarized, and included in this report for dates from October 1, 2013 through September 30, 2014. DW-1 Injection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from twice daily samplings during injection periods; additional raw data can be provided upon request. Attachment 4 is a graphical representation of the tabular data. Oooguruk Development Project DW-1 2013-2014 Annual Performance Report October 20, 2014 Page 2 of 3 DW-1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. Attachment 3 includes a summary of physical, chemical, and other relevant characteristics of the injected fluids. Assessment of Fracture Geometry No additional assessment has been completed since the modeling done in June 2008 that supported a six barrels per minute (bpm) injection rate and 14 pounds per gallons (ppg). Description of Anomalous Injection Results Attachment 4 includes a graphical plot of injection rate and tubing pressure. Injection rates momentarily exceeded six bpm on the following date: • 01/08/2014 - 13.41 bpm Following a review of injection data, it was determined that the anomaly was an erroneous recording of the injection rate. At the time of the injection rate spike, only one disposal pump was being utilized and was pumping at a rate of four bpm. Furthermore, the maximum injection rate of a single disposal pump cannot exceed six bpm with the current gear and plunger configuration of the disposal pumps. Calculated Zone of Influence for Injection Fluids No changes have been made since Caelus submitted a model in June 2008 that supported the current injection rate of six bpm. The zone of influence is still considered to be similar to modeling conducted for this disposal operation. Other Attachment 5 includes the results of the annual mechanical integrity test (MIT) performed on July 28, 2014. The MIT was witnessed by Thor Cutler with EPA. Johnnie Hill with AOGCC waived witness of the test (via email communication) on July 23, 2014. If you have any questions or require additional information, please contact Darren Burks by phone at (907) 343-2103 or by email at darren.burks@caelusenergy.com. Thank you. Sincere , Vern Johnson Drilling and Completions Manager Caelus Natural Resources Alaska, LLC Enclosures: Attachment 1: DW-1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals Oooguruk Development Project DW-1 2013-2014 Annual Performance Report October 20, 2014 Page 3 of 3 Attachment 3: Waste Streams Summary Attachment 4: Pressure Plot of Injection Data Attachment 5: MIT -IA July 2014 Test Results Attachment 1 Date Average Injection Rate (bbl/min)F Average Injection Pressure (psi)WH Average Temperature (°F) Maximum Injection Rate (bbl/min) Maximum Injection Pressure (psi) Minimum Injection Pressure (psi) 1-Oct-13 5.29 2,3491 65 5.80 2,465 2,022 2-Oct-13 4.03 2,388 67 5.80 2,828 1,872 3-Oct-13 3.70 2,414 71 5.80 2,841 2,250 4-Oct-13 2.38 2,346 87 5.06 2,538 2,059 5-Oct-13 4.24 2,247 72 5.80 2,472 2,088 6-Oct-13 4.37 2,348 63 5.81 2,477 2,128 7-Oct-13 3.94 2,485 61 5.81 2,863 1,843 8-Oct-13 4.53 2,361 63 5.82 2,496 2,110 9-Oct-13 3.95 2,317 60 5.81 2,496 2,021 10-Oct-13 4.81 2,374 61 5.81 2,510 2,166 11-Oct-13 4.41 2,348 75 5.81 2,504 2,142 12-Oct-13 0.00 0 0 0.00 0 0 13-Oct-13 3.86 2,358 67 5.80 2,605 1,824 14-Oct-13 3.89 2,368 53 4.06 2,432 2,300 15-Oct-13 4.71 2,378 65 5.83 2,503 2,224 16-Oct-13 5.00 2,385 55 5.82 2,486 2,105 17-Oct-13 4.76 2,390 63 5.91 2,505 2,100 18-Oct-13 5.39 2,405 54 5.84 2,487 2,220 19-Oct-13 4.83 2,384 66 5.85 2,494 2,081 20-Oct-13 4.09 2,350 84 5.83 2,553 2,196 21-Oct-13 4.45 2,303 74 5.83 2,422 2,128 22-Oct-13 4.87 2,346 63 5.96 2,487 2,071 23-Oct-13 5.00 2,360 57 5.86 2,522 2,017 24-Oct-13 4.84 2,333 57 5.95 2,493 2,079 25-Oct-13 4.86 2,364 68 5.95 2,507 2,108 26-Oct-13 3.64 2,291 75 4.06 2,494 2,103 27-Oct-13 4.19 2,391 57 5.79 2,480 2,149 28-Oct-13 4.74 2,412 55 5.90 2,522 2,146 29-Oct-13 5.49 2,427 60 5.85 2,494 2,219 30-Oct-13 5.33 2,401 55 5.80 2,488 2,073 31-Oct-13 4.87 2,386 58 5.81 2,491 2,058 1-Nov-13 3.98 2,391 71 5.84 2,460 1,997 2-Nov-13 0.00 0 0 0.00 0 0 3-Nov-13 3.77 2,347 68 4.05 2,462 2,126 4-Nov-13 3.73 2,376 59 4.04 2,437 2,248 5-Nov-13 3.90 2,354 49 4.04 2,440 2,129 6-Nov-13 4.93 2,402 57 5.82 2,494 2,088 7-Nov-13 4.04 2,188 68 5.83 2,5361 1,931 8-Nov-13 4.59 2,288 54 5.83 2,547 1,936 9-Nov-13 4.29 2,210 66 5.82 2,520 1,954 10-Nov-13 4.37 2,313 64 5.98 2,557 1,977 11-Nov-13 4.011 2,348 71 5.82 2,621 2,029 12-Nov-13 3.69 2,472 63 5.79 2,859 2,102 Page 1 of 8 Attachment 1 13-Nov-13 5.15 2,520 50 5.84 2,580 2,202 14-Nov-13 4.47 2,379 68 5.87 2,597 2,145 15-Nov-13 5.18 2,540 55 5.86 2,625 2,299 16-Nov-13 4.32 2,467 60 5.88 2,647 2,177 17-Nov-13 4.18 2,463 70 5.93 2,683 2,065 18-Nov-13 3.83 2,544 69 5.83 2,933 2,205 19-Nov-13 4.03 2,458 70 5.87 2,636 2,150 20-Nov-13 4.57 2,491 68 5.84 2,678 2,206 21-Nov-13 4.14 2,561 65 5.84 3,015 2,093 22-Nov-13 4.26 2,470 69 5.83 2,841 2,159 23-Nov-13 4.41 2,484 60 5.83 2,671 1,996 24-Nov-13 4.58 2,425 63 5.84 2,618 2,062 25-Nov-13 5.03 2,493 59 5.86 2,608 2,184 26-Nov-13 5.31 2,520 53 5.82 2,565 2,381 27-Nov-13 4.72 2,473 62 5.85 2,571 2,113 28-Nov-13 4.06 2,448 56 5.82 2,576 1,708 29-Nov-13 4.63 2,474 60 5.81 2,566 2,013 30-Nov-13 4.58 2,504 62 5.81 2,892 2,203 1-Dec-13 4.73 2,473 60 5.84 2,573 2,307 2-Dec-13 4.97 2,408 60 5.86 2,582 1,976 3-Dec-13 4.69 2,340 62 5.86 2,597 1,855 4-Dec-13 4.88 2,438 62 5.96 2,698 2,004 5-Dec-13 4.44 2,336 72 5.81 2,612 1,944 6-Dec-13 4.41 2,252 78 5.83 2,600 1,708 7-Dec-13 4.58 2,226 75 5.98 2,618 1,688 8-Dec-13 4.56 2,281 64 5.83 2,593 1,890 9-Dec-13 4.18 2,342 68 5.87 2,608 1,858 10-Dec-13 3.70 2,276 62 4.10 2,512 1,911 11-Dec-13 3.87 2,414 60 4.05 2,5271 2,045 12-Dec-13 3.80 2,441 52 4.09 2,505 2,168 13-Dec-13 5.34 2,480 49 5.95 2,568 1,871 14-Dec-13 4.40 2,204 71 5.89 2,545 1,882 15-Dec-13 4.98 2,394 60 5.96 2,565 1,756 16-Dec-13 5.08 2,462 54 5.84 2,5941 1,683 17-Dec-13 5.22 2,493 43 5.83 2,582 2,119 18-Dec-13 5.07 2,459 48 5.93 2,562 1,936 19-Dec-13 4.56 2,403 67 5.81 2,566 2,180 20-Dec-13 4.60 2,392 59 5.82 2,580 1,928 21-Dec-13 4.72 2,436 53 5.95 2,587 2,253 22-Dec-13 5.27 2,506 47 5.81 2,557 2,007 23-Dec-13 5.33 2,517 47 5.83 2,594 2,033 24-Dec-13 4.61 2,461 58 5.95 2,575 2,075 25-Dec-13 5.09 2,520 47 5.83 2,586 2,140 26-Dec-13 5.26 2,499 46 5.84 2,583 2,054 27-Dec-13 4.39 2,520 64 5.86 2,607 2,061 28-Dec-13 5.29 2,492 46 5.861 2,582 2,018 29-Dec-13 4.51 2,439 61 5.841 2,6121 2,081 Page 2 of 8 Attachment 1 30-Dec-13 4.75 2,446 56 5.82 2,557 2,064 31-Dec-13 4.84 2,500 47 5.86 2,600 2,148 1-Jan-14 4.99 2,486 50 5.80 2,556 2,054 2-Jan-14 4.59 2,425 52 5.80 3,926 2,034 3-Jan-14 4.50 2,452 52 5.80 2,601 2,015 4-Jan-14 5.16 2,479 46 5.80 2,577 2,062 5-Jan-14 4.80 2,496 60 5.80 2,569 2,302 6-Jan-14 5.25 2,461 46 5.80 2,563 1,995 7-Jan-14 4.81 2,467 55 5.80 2,592 2,001 8-Jan-14 4.28 2,339 62 13.41 2,611 2,102 9-Jan-14 4.50 2,358 60 5.80 2,675 2,063 10-Jan-14 4.08 2,355 64 5.80 2,656 2,094 11-Jan-14 4.12 2,391 73 5.80 2,673 2,165 12-Jan-14 4.31 2,461 73 5.80 2,655 2,234 13-Jan-14 4.32 2,390 67 5.87 2,617 2,185 14-Jan-14 4.89 2,476 53 5.94 2,604 2,139 15-Jan-14 4.26 2,448 49 5.85 2,604 2,021 16-Jan-14 4.66 2,381 58 5.87 2,600 2,107 17-Jan-14 4.61 2,467 54 5.80 2,588 2,009 18-Jan-14 4.26 2,469 52 5.79 2,642 2,036 19-Jan-14 4.39 2,449 59 5.79 2,646 2,073 20-1an-14 4.37 2,475 58 5.79 2,598 2,029 21-Jan-14 4.25 2,439 61 5.82 2,661 2,115 22-Jan-14 4.53 2,446 56 5.82 2,621 2,107 23-Jan-14 4.56 2,425 57 5.79 2,621 2,006 24-1an-14 4.46 2,500 52 5.79 2,625 2,147 25-Jan-14 4.64 2,460 61 5.79 2,637 2,192 26-Jan-14 4.77 2,480 62 5.79 2,634 2,246 27-Jan-14 4.60 2,473 64 5.81 2,638 2,086 28-Jan-14 4.77 2,465 57 5.84 2,618 2,010 29-Jan-14 4.64 2,446 59 5.79 2,622 2,101 30-Jan-14 4.66 2,516 53 5.79 2,632 2,114 31-1an-14 3.80 2,506 46 3.99 2,579 2,076 1-Feb-14 3.77 2,497 56 4.04 2,584 2,064 2-Feb-14 3.81 2,489 58 4.06 2,607 2,142 3-Feb-14 3.74 2,498 53 4.23 2,598 2,211 4-Feb-14 3.82 2,511 58 4.04 2,613 2,235 5-Feb-14 4.63 2,551 60 5.80 2,656 2,184 6-Feb-14 5.19 2,566 43 5.80 2,651 2,125 7-Feb-14 5.18 2,566 46 5.79 2,648 2,134 8-Feb-14 5.46 2,541 52 5.79 2,572 2,286 9-Feb-14 4.51 2,540 65 5.85 2,628 2,095 10-Feb-14 4.55 2,523 56 5.79 2,619 2,071 11-Feb-14 5.25 2,522 46 5.79 2,614 2,059 12-Feb-14 5.28 2,525 46 5.86 2,602 2,253 13-Feb-14 4.87 2,507 54 5.85 2,614 2,099 14-Feb-14 5.14 2,504 46 5.85 2,6021 2,085 Page 3 of 8 Attachment 1 15-Feb-14 4.93 2,508 50 5.85 2,612 2,107 16-Feb-14 4.64 2,509 50 5.82 2,619 2,204 17-Feb-14 5.41 2,519 44 5.82 2,605 2,136 18-Feb-14 4.66 2,480 63 5.82 2,614 2,281 19-Feb-14 5.35 2,507 45 5.83 2,596 2,141 20-Feb-14 5.11 2,502 51 5.86 2,622 2,018 21-Feb-14 5.28 2,502 45 5.80 2,597 2,115 22-Feb-14 4.69 2,512 60 5.83 2,614 2,085 23-Feb-14 5.17 2,490 45 5.80 2,597 2,029 24-Feb-14 5.34 2,500 46 5.83 2,600 2,026 25-Feb-14 4.63 2,444 56 5.80 2,619 2,237 26-Feb-14 4.70 2,355 69 5.83 2,619 2,056 27-Feb-14 4.25 2,397 66 5.83 2,618 2,005 28-Feb-14 4.39 2,381 69 5.88 2,642 2,053 1-Mar-14 5.24 2,500 50 5.79 2,556 2,214 2-Mar-14 4.38 2,245 61 5.89 2,622 1,937 3-Mar-14 4.33 2,241 64 5.87 2,588 1,904 4-Mar-14 4.20 2,410 62 5.92 2,904 1,917 5-Mar-14 5.23 2,492 44 5.84 2,561 2,058 6-Mar-14 5.12 2,524 44 5.80 2,712 2,130 7-Mar-14 4.90 2,476 49 5.811 2,578 2,038 8-Mar-14 4.26 2,437 59 5.80 2,591 2,149 9-Mar-14 4.45 2,454 52 5.80 2,592 2,107 10-Mar-14 4.74 2,494 51 5.80 2,586 2,006 11-Mar-14 3.61 2,607 49 5.82 2,920 2,183 12-Mar-14 0.00 0 0 0.00 01 0 13-Mar-14 4.54 2,565 52 5.80 2,836 2,112 14-Mar-14 4.09 2,611 55 6.06 2,965 2,068 15-Mar-14 3.89 2,550 62 5.84 2,924 2,144 16-Mar-14 3.54 2,667 62 4.08 2,985 2,260 17-Mar-14 4.63 2,566 57 5.81 2,753 2,255 18-Mar-14 4.49 2,509 62 5.82 2,665 2,194 19-Mar-14 5.38 2,591 47 5.78 2,651 2,323 20-Mar-14 4.48 2,611 61 5.88 3,009 2,307 21-Mar-14 4.42 2,752 45 5.82 2,993 2,308 22-Mar-14 4.30 2,569 53 5.88 2,817 2,317 23-Mar-14 3.52 2,712 59 5.78 2,920 2,324 24-Mar-14 4.20 2,568 51 5.81 2,645 2,304 25-Mar-14 4.08 2,547 69 5.81 2,899 2,263 26-Mar-14 4.40 2,611 66 5.90 2,877 2,461 27-Mar-14 3.85 2,541 50 4.05 2,581 2,389 28-Mar-14 3.58 2,610 52 3.99 2,947 2,155 29-Mar-14 3.74 2,622 44 4.02 2,958 2,174 30-Mar-14 0.00 0 0 0.00 0 0 31-Mar-14 3.75 2,585 67 4.06 2,901 2,324 1-Apr-14 3.85 2,600 45 4.02 2,889 2,287 2-Apr-14 3.85 2,564 45 4.01 2,5941 2,109 Page 4 of 8 Attachment 1 3-Apr-14 3.61 2,590 79 5.78 2,990 2,283 4-Apr-14 4.42 2,451 61 5.80 2,729 2,213 5-Apr-14 3.38 2,595 62 5.77 3,014 2,116 6-Apr-14 3.67 2,681 67 5.79 3,077 2,204 7-Apr-14 3.76 2,762 71 4.11 3,081 2,155 8-Apr-14 3.77 2,532 63 4.04 2,728 2,255 9-Apr-14 4.44 2,621 63 5.77 2,787 2,398 10-Apr-14 3.94 2,597 62 5.77 2,899 2,356 11-Apr-14 4.10 2,605 57 5.88 2,808 2,251 12-Apr-14 3.59 2,798 77 5.75 3,198 2,568 13-Apr-14 3.91 2,724 63 5.77 2,991 2,493 14-Apr-14 3.94 2,898 54 5.79 3,225 2,542 15-Apr-14 3.94 2,804 73 5.81 3,189 2,454 16-Apr-14 4.01 2,633 62 5.86 2,853 2,228 17-Apr-14 3.97 2,624 65 5.79 2,765 2,278 18-Apr-14 3.81 2,607 71 4.14 2,821 2,079 19-Apr-14 3.75 2,684 76 4.05 2,824 2,179 20-Apr-14 3.55 2,775 77 4.08 2,850 2,498 21-Apr-14 4.10 2,794 63 5.77 2,881 2,611 22-Apr-14 4.53 2,764 64 5.87 2,880 2,555 23-Apr-14 3.78 2,758 52 4.04 2,897 2,475 24-Apr-14 3.66 2,773 60 4.06 2,916 2,582 25-Apr-14 3.64 2,893 59 4.07 3,307 2,672 26-Apr-14 3.40 3,039 64 4.08 3,264 2,664 27-Apr-14 3.47 2,994 63 4.04 3,217 2,745 28-Apr-14 3.61 2,833 45 4.04 2,950 2,646 29-Apr-14 3.76 2,753 47 4.08 2,908 2,471 30-Apr-14 3.77 2,767 53 4.09 2,897 2,529 1-May-14 3.74 2,817 46 4.05 2,858 2,545 2-May-14 3.78 2,779 54 4.06 2,875 2,487 3-May-14 3.79 2,640 53 4.04 2,806 2,441 4-May-14 3.59 2,751 47 4.03 2,841 2,395 5-May-14 4.16 2,809 52 5.78 2,884 2,518 6-May-14 3.61 2,697 48 4.02 2,729 2,541 7-May-14 4.11 2,722 53 5.78 2,838 2,331 8-May-14 3.85 2,691 53 4.10 2,754 2,390 9-May-14 3.57 2,719 53 4.04 2,938 2,279 10-May-14 4.86 2,692 47 5.78 2,765 2,225 11-May-14 4.40 2,674 52 5.80 2,810 2,276 12-May-14 5.37 2,666 47 5.79 2,763 2,215 13-May-14 4.921 2,607 46 5.81 2,731 2,258 14-May-14 4.381 2,648 56 5.79 2,720 2,183 15-May-14 5.49 2,618 45 5.81 2,723 2,161 16-May-14 3.19 2,576 55 5.81 2,933 2,157 17-May-14 3.88 2,6241 59 4.16 2,716 2,156 18-May-14 3.82 2,5151 531 4.03 2,626 2,171 19-May-141 3.811 2,6681 561 5.791 3,018 2,092 Page 5 of 8 Attachment 1 20-May-14 5.52 2,550 49 5.84 2,621 2,167 21-May-14 3.80 2,490 57 4.19 2,637 2,055 22-May-14 4.06 2,688 74 5.81 3,107 2,012 23-May-14 4.00 2,638 56 5.83 3,036 2,218 24-May-14 3.96 2,650 58 5.78 3,070 2,230 25-May-14 4.36 2,607 54 5.77 2,694 2,199 26-May-14 4.59 2,584 53 5.79 2,646 2,099 27-May-14 4.87 2,550 50 5.80 2,633 2,148 28-May-14 3.74 2,686 56 4.36 3,084 2,218 29-May-14 3.65 2,758 58 5.79 3,088 2,250 30-May-14 3.48 2,563 58 4.05 2,660 2,303 31-May-14 3.20 2,467 55 4.02 2,638 2,157 1-Jun-14 3.80 2,554 68 4.02 2,662 2,230 2-Jun-14 5.47 2,515 52 5.80 2,575 2,157 3-Jun-14 2.60 2,452 60 5.78 2,808 2,155 4-Jun-14 3.64 2,491 56 5.87 2,599 2,304 5-Jun-14 3.70 2,488 55 4.12 2,617 2,129 6-Jun-14 4.85 2,513 48 5.79 2,580 2,101 7-Jun-14 3.88 2,486 53 4.14 2,644 2,125 8-Jun-14 0.00 0 0 0.00 0 0 9-Jun-14 4.09 2,572 69 5.78 2,830 2,224 10-Jun-14 3.88 2,491 77 4.01 2,523 2,341 11-Jun-14 3.66 2,393 55 4.00 2,447 2,230 12-1un-14 0.00 0 0 0.00 0 0 13-Jun-14 3.64 2,447 67 4.08 2,524 2,120 14-Jun-14 3.54 2,438 58 4.00 2,550 2,107 15-1un-14 3.63 2,372 49 4.00 2,453 2,170 16-Jun-14 3.54 2,404 53 4.00 2,580 2,121 17-Jun-14 3.43 2,446 56 4.00 2,562 2,169 18-Jun-14 3.88 2,422 47 4.01 2,469 2,232 19-Jun-14 3.66 2,499 54 3.98 2,891 2,126 20-Jun-14 4.02 2,505 52 4.31 2,577 2,196 21-Jun-14 4.13 2,416 46 4.32 2,492 2,175 22-Jun-14 3.90 2,422 49 4.05 2,4891 2,197 23-Jun-14 3.90 2,407 57 4.31 2,464 2,174 24-Jun-14 3.67 2,400 51 4.00 2,506 2,001 25-Jun-14 5.79 2,551 46 5.79 2,560 2,546 26-1un-14 3.77 2,424 47 4.01 2,475 2,253 27-Jun-14 3.91 2,417 46 4.01 2,483 2,199 28-Jun-14 3.93 2,440 45 4.01 2,506 2,244 29-1un-14 3.90 2,443 46 4.00 2,570 2,217 30-Jun-14 3.69 2,504 63 4.01 2,601 2,225 1-Jul-14 3.36 2,516 81 4.04 2,6421 2,363 2-Jul-14 5.52 2,471 50 5.85 2,543 2,210 3-Jul-14 3.80 2,509 52 4.0.2 2,628 2,210 4-Jul-14 3.931 2,439 46 4.00 2,491 2,282 5-Jul-14 5.511 2,480 47 5,791 2,544 2,234 Page 6 of 8 Attachment 1 6-Jul-14 0.00 0 0 0.00 0 0 7-Jul-14 5.52 2,437 59 5.88 2,514 2,219 8-Jul-14 3.96 2,500 64 5.80 2,602 2,272 9-Jul-14 3.76 2,590 61 5.84 2,638 2,294 10-Jul-14 3.68 2,614 66 4.17 2,645 2,555 11-Jul-14 4.50 2,449 51 5.79 2,530 2,203 12-Jul-14 4.04 2,489 56 5.79 2,652 2,169 13-Jul-14 5.42 2,494 46 5.80 2,558 2,277 14-Jul-14 3.74 2,452 48 4.29 2,648 2,199 15-Jul-14 3.83 2,466 64 4.04 2,589 2,254 16-Jul-14 0.00 0 0 0.00 0 0 17-Jul-14 3.77 2,534 79 4.06 2,798 2,142 18-Jul-14 3.89 2,512 50 4.03 2,563 2,433 19-Jul-14 3.73 2,517 53 4.12 2,616 2,388 20-Jul-14 3.84 2,487 48 4.00 2,506 2,328 21-Jul-14 3.74 2,521 54 4.04 2,633 2,291 22-Jul-14 3.87 2,455 63 4.15 2,506 2,364 23-Jul-14 0.00 0 0 0.00 0 0 24-Jul-14 3.81 2,760 67 4.04 2,938 2,212 25-Jul-14 3.80 2,470 64 4.04 2,911 1,976 26-Jul-14 3.41 2,528 47 4.04 2,549 2,423 27-Jul-14 3.85 2,472 55 4.05 2,574 2,163 28-Jul-14 3.68 2,480 50 4.03 2,551 2,177 29-Jul-14 3.67 2,368 78 4.04 2,565 2,148 30-Jul-14 4.33 2,609 49 5.84 2,952 2,287 31-Jul-14 3.84 2,423 61 4.06 2,599 2,162 1-Aug-14 3.94 2,513 47 4.01 2,528 2,324 2-Aug-14 3.89 2,488 50 3.99 2,537 2,124 3-Aug-14 3.87 2,255 74 5.78 2,615 1,965 4-Aug-14 4.05 2,249 71 5.78 2,741 1,838 S-Aug-14 4.86 2,454 56 5.85 2,612 2,040 6-Aug-14 4.53 2,501 48 5.85 2,579 2,057 7-Aug-14 5.53 2,533 48 5.91 2,580 2,060 8-Aug-14 4.10 2,488 58 5.84 2,615 2,050 9-Aug-14 4.12 2,289 69 5.78 2,668 2,049 10-Aug-14 3.64 2,482 55 3.98 2,523 2,218 11-Aug-14 4.22 2,530 60 5.78 2,828 2,115 12-Aug-14 4.18 2,520 60 5.77 2,698 2,283 13-Aug-14 3.79 2,522 55 4.01 2,625 2,101 14-Aug-14 0.00 0 0 0.00 0 0 15-Aug-14 3.78 2,548 57 4.07 3,043 2,209 16-Aug-14 3.85 2,523 45 3.97 2,624 2,181 17-Aug-14 3.71 2,509 64 4.07 3,044 1,877 18-Aug-14 3.83 2,496 54 4.20 2,632 2,175 19-Aug-14 3.77 2,564 56 4.19 3,0471 2,149 20-Aug-14 3.68 2,654 58 4.09 2,9871 2,200 21-Aug-14 2.65 2,643 61 4.01 2,9911 2,265 Page 7 of 8 Attachment 1 22-Aug-14 3.69 2,496 58 4.08 2,654 2,007 23-Aug-14 1.28 1,851 70 2.03 1,937 1,792 24-Aug-14 2.34 2,279 65 4.00 2,609 2,065 25-Aug-14 2.52 2,284 60 4.01 2,617 1,930 26-Aug-14 1.90 2,238 61 4.02 2,621 1,992 27-Aug-14 2.28 2,378 61 5.76 2,682 1,996 28-Aug-14 3.89 2,461 61 5.80 2,680 2,154 29-Aug-14 0.00 0 0 0.00 0 0 30-Aug-14 4.58 2,526 64 5.82 2,790 2,183 31-Aug-14 5.31 2,558 47 5.79 2,664 2,073 1-Sep-14 4.01 2,408 66 5.79 2,673 2,041 2-Sep-14 3.79 2,370 67 4.06 2,641 2,138 3-Sep-14 3.90 2,423 65 5.77 2,701 2,112 4-Sep-14 3.69 2,561 66 4.10 3,013 2,156 5-Sep-14 3.68 2,723 65 4.06 3,036 2,352 6-Sep-14 3.81 2,719 65 4.05 3,053 2,336 7-Sep-14 3.71 2,659 58 4.02 2,748 2,487 8-Sep-14 4.28 2,626 68 5.84 2,761 2,250 9-Sep-14 4.49 2,715 68 5.83 2,879 2,517 10-Sep-14 3.81 2,703 59 4.05 2,795 2,528 11-Sep-14 3.70 2,756 50 4.07 2,926 2,547 12-Sep-14 3.70 2,700 71 4.02 2,828 2,505 13-Sep-14 3.74 2,675 70 4.05 2,821 2,515 14-Sep-14 3.78 2,690 64 4.03 2,826 2,456 15-Sep-14 3.66 2,719 61 4.03 2,8351 2,485 16-Sep-14 3.50 2,724 69 4.03 3,065 2,494 17-Sep-14 3.78 2,705 73 4.04 2,846 2,491 18-Sep-14 3.83 2,749 65 3.99 2,892 2,556 19-Sep-14 4.71 2,758 64 5.81 2,949 2,450 20-Sep-14 3.78 2,720 80 4.01 2,7981 2,567 21-Sep-14 4.30 2,740 54 5.81 2,894 2,312 22-Sep-14 4.64 2,736 66 5.84 2,894 2,468 23-Sep-14 4.04 2,845 63 5.82 3,164 2,425 24-Sep-14 2.80 2,570 71 3.97 2,716 2,272 2S-Sep-14 3.09 2,809 75 4.09 3,139 2,251 26-Sep-14 4.15 2,900 66 5.77 3,181 2,430 27-Sep-14 4.22 2,696 57 5.77 3,150 2,270 28-Sep-14 3.64 2,618 66 5.76 2,790 2,157 29-Sep-14 3.85 2,626 47 4.031 2,6791 2,294 30-Sep-14 3.81 2,529 71 4.031 2,7621 2,273 Page 8 of 8 Attachment 2 - Monthly Injection Totals ODSDW1-44 Monthly Injection Totals Month Volume of Injected Fluid (BBLS) October 2013 32,761 November 2013 55,418 December 2013 40,184 January 2014 58,625 February 2014 33,912 March 2014 44,940 April 2014 65,112 May 2014 36,958 June 2014 19,447 July 2014 29,560 August 2014 36,537 September 2014 50,349 2013-2014 Annual Performance Review for Oooguruk Unit DW-1 Caelus Natural Resources Alaska, LLC October 20, 2014 Page 1 of 1 Attachment 3 - Waste Streams Summary October 1, 2013 to September 30, 2014 Physical, Chemical, and Other Relevant Characteristics of the Injected Fluids Non -Exempt Typical Primary Constituents Sampling Conducted or Waste Streams Non -Exempt Sources Generator/Process Knowledge • Incidental non -hazardous wastes Wash water, seawater used generated by module operations & for drilling mud make-up, Waste characterization sampling Utility modules sump maintenance potable water chemical completed and verified not RCRA- fluids • Incidental equipment leaks additives. Process control is hazardous — Confirmation sample • Additives for Reverse Osmosis & potable strictly maintained collected 05/11/14 water systems Glycol/heat exchange • Vehicles & equipment (antifreeze) Glycol (MEG, DEG, TEG, Waste characterization sampling completed and verified not RCRA- media • Module and facility heating and cooling propylene) hazardous — Generator knowledge systems used Non-exempt spill • Fluids recovered from cleanup of non- Water, snow, gravel, with Waste characterization sampling completed and verified not RCRA- clean-up exempt spills hydrocarbon or chemical hazardous —Confirmation samples • Spill impacted gravel or snow products collected 02/08/14 Water, glycol, possible Waste characterization sampling Hydrotest fluid • Pressure test new or non-exempt process product residual in existing completed and verified not RCRA- (water or glycol only) lines, vessels lines, traces of chlorine or hazardous — Generator knowledge other biocide used Boiler blowdown • Rig or production facility boilers Water Not injected year to date, fluids used for drilling mud make-up water Off spec product • Products spilled, out -dated or no longer Varies — MSDSs reviewed Not injected year to date acceptable for original purpose Contained snow/ • Outdoor containment around fuel and Water, possible traces of Waste characterization sampling completed and verified not RCRA- ponded water chemical storage tanks hydrocarbon or chemicals if hazardous — Generator knowledge . Depressions on or between pads & roads there have been spills used • Motor oil Routine verification sampling Lubrication oil • Transmission fluid Hydrocarbons/water mixes conducted to confirm not RCRA- hazardous — Typically sent to hydrocarbon or offsite recycle • Internal or external washdown of skids, modules Water, possible traces of Waste characterization sampling Non-exempt facility • Equipment cleaning (using non- hydrocarbon, chemicals, completed and verified not RCRA- wash water hazardous detergents or degreasers) detergent hazardous — Generator knowledge • Residues removed from RCRA-empty used containers Waste characterization sampling Incineratorash • Trash and camp waste Particulates/RCRA metals completed and verified not RCRA- . Sewage sludge hazardous —Generator knowledge g used Domestic • Camp wastewater treatment plant(s) and Water, soap residuals, human NPDES permitted facility, RCRA wastewater/ sludge site enviro-vacs waste Exempt Waste characterization sampling Reverse osmosis • Saline concentrate from reverse osmosis completed and verified not RCRA- concentrate/seawater Process for making potable water from Saline water hazardous — Generator knowledge seawater used Notes: 1. Similar wastes maybe RCRA exempt, depending on waste -generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 m 4-0 L Q) LL O N O M CL a) V) O 4-1 r-I O N U O W cf i !4 Cf [f' r-I O i aJ .0 U fa Q c 00,6 000c ooSz Oooz oc,L 000L OO, 0 RID l Id vud 00 R v V LOZA0, Wd000L V LOUVUS Wd00LLOL V LOZIFAI rN o0z L. t V LOU9U1 rN00LOv V LOU t i lw OO ZO L v LOU9U9 W 00 L5 6 V LOZJ t vq Wd0OZ,zL V LOULUS Wd00LVc V LOW ti5 Wd OO zV'4 v LOULZIV Wd OO L6 6 V LOZIZ vv w oo cM VLOU6UC wv00Lzc V LOUV UC rN 00Zz 5 V LOULZAZ WV OO-L t 8 V LOUZ VZ vw 00 z V Ll V LOZJ8Z! L rid 00 LOZ vLOUcvI Wd 00 Ms C LOUWZ L Vid co L51 C LOZJV VZ L vyd 00 Z9 0 L c toZi67i L L WV 00 LO L ctozrsuLL YIN 00 zKV C LOU LCJO L M00LCL cWNvoL wN00zc0t cLOU UOL 11 Ot Ott h 10 to V M " •- 0 wd 00 LZ. v V t0U8J6 rid OO zz t VtOUVU9 rid 001 t O t VLOVUR rN OOZ v t v LOU9UL rN Oo Lo'V VLOUtVL viv DO Zo l V LOU9U9 VW00L88 V t0U t tl9 nd OOZ9 Z t V tOULZ19 rid 00 Lk v W?JZ V, rid OOZY 9 V LOULUV wd OOLC'6 V WZ9 vp rN00ZCZL v L0zJ6zlc rN OO LZ C zA V LOUV LJC PN 00 Ms VLOULUZ rN 00 L 1'8 VtoUZvz Piv'00zLILL V LOUSU L Wd OO LOZ V LOUc v L rid 00 to c tw6zrz t r7d OO L9 L C vpLJZt Pod OOZS Ot C iOU6U l l rN 00 LV : L cwrJsutt rN 00 zV'v c LOZJ tuo t VWOOLCL c t0U9 vo t riv OO:zc O t CLODUOL Attachment 5 — MIT -IA Test Results a# iYA+I United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor< epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Permit No. PTD No. Pioneer - OoogurukIInit ODSDWOI-44 AK-II009-A 207-140 Injector M17"1'�pe hest'1}PC Pest Date Class I T X IA Std. Annular Pressure "hest (SAPT) 7/6162014 Req'd Test Presssure (psi) I, luid "rype(s) used to test Packer Depth (ft, 'I VD) test Interval /Comments 3,500 8.4 ppg seawater 4,999 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test If on injection, note injection rate, injection pressure and injection fluid temperature Note volume ofdiesel/50:50 methanol/glycol pumped in annulus during test. T E S START'TIME: , qo RECORDED PRESSURES (PSI) RESULT P/F PRE MIT INI FIAt. 15 MIN 30 MIN 45 MIN 60 A]LN "TUBING 22-q ZZze T INNER ANNULUS OUTER ANNULUS i Z. Lic 2v 2U 1 COMMENTS: a.1MP 1 `� G rt T E STARTTIME: RE.CORDF:DPRESSURES (PSI) RF:SUI:L PRE MIT INI"rlAl. 15 MIN 30 N11N 45 MIN 60 MIN S TUBING T INNER ANNULUS OUTER ANNULUS 2 COMMENTS: T E START'TIME: RECORDED PRESSURES (PSI) RESULT PRE ;Nil I INrr1A1, 15 NIIN 30 NUN 45 MIN 60 MIN S TUBING I,ASS, T INNERANNULUS FAIT OUTER ANNULUS 3 COMMENTS: VIISC COMMENTS. 1) Total pressure loss must be less than 10 % at end ol'30 minute. test 2) Pressure loss in last 15 minutes must he less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or> 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). o-- F -mail this Ndfr'fest Data Form to EPA Region i0 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler/Jason Selitsch ( Gti c t� PC/- ')akAiv.e ii'll r-I O N 00 N N L F- a-J N Q) L V) N v L L co Q L c c� V) From: Hill. Johnnie W (DOA) To: Hartwig. Dennis Cc: DOA AOGCC Prudhoe Bay Subject: Re: AOGCCI Test Witness Notification Request: MIT, Oooguruk ODS DW1-44 Date: Wednesday, July 23, 2014 7:07:44 AM Witness is waived Johnnie Hill CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Johnnie Hill at 907-659- 2714 or johnnie.hill(clalaska.gov On Jul 21, 2014, at 13:53, "Dennis Hartwig" <nor p)1C&formresponse.com> wrote: Answer Question Type of Test MIT Requested: Requested Time for 07-28-2014 12:00 PM Inspection Location Oooguruk ODS DW1-44 Name Dennis Hartwig E-mail dennis hartwig(acaelusenergy com Phone Number (907) 3432174 Company Caelus Natural Resources Alaska LLC Planning our annual MITIA on our disposal well. Test will be witnessed by EPA (Thor Cutler & Jason Selitsch). Other Information: Please let me know if you would like to witness the test. Submission ID: 281788788012877338 14 -:� PIONEER:.. NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277-2700 Fax: (907) 343-2190 October 29, 2013 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2012-2013 Annual Performance Review for Oooguruk Unit DW 1 Dear Commissioner Foerster: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW-1), in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) Disposal Injection Order No 31, Rule 6. This surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by November 1 of each year and include data sufficient to characterize the disposal operation: • Pressures and injection rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW-1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, summarized, and included in this report for dates from October 1, 2012 through September 30, 2013. DW-1 Injection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from twice daily samplings during injection periods; additional raw data can be provided upon request. Attachment 6 is a graphical representation of the tabular data. Oooguruk Development Projf • DW-1 2010-2011 Annual Performance Report October 29, 2013 Page 2 DW-1 Fluid Volumes Iniected Attachment 2 outlines the fluid volumes injected on a monthly basis. Attachment 3 includes a summary of physical, chemical, and other relevant characteristics of injected fluids. Assessment of Fracture Geometry No additional assessment has been completed since the modeling done in June 2008 that supported a 6 bpm injection rate and 14 ppg. Description of Anomalous Injection Results Attachment 6 is a graphical plot of injection, rate and tubing pressure. Injection rates momentarily exceeded 6 bpm on the following dates; • 04/04/13 - 6.08 bpm • 04/10/2013 — 6.04 bpm • 06/10/13 — 6.09 bpm • 09/09/13 — 6.01 bpm Pioneer injection procedures require that the operator attempt to maintain an injection rate at less than 5.8bpm. In the case of all listed anomalous events, air became entrained in the inlet side of the pump and injection rate momentarily spiked due to increased pump speed. After investigation all anomalous rate events occurred for a brief moment and were not sustained. Calculated Zone of Influence for Injection Fluids No changes have been made since Pioneer submitted a model in June 2008 that supported the current injection rate of 6 bpm. The Zone of Influence is still considered to be similar to modeling conducted for this disposal operation. Other Attachments 4(a) - 4(g) is the Mechanical Integrity Test witnessed by the EPA and the AOGCC email waiving witness of the test from Bob Noble that was conducted on the inner annulus on January 27, 2013. Attachments 5(a) - 5(m) is the Mechanical Integrity Test witnessed by the EPA and the AOGCC that were conducted before and after the scheduled repair workover during August 2013. (NOTE: AOGCC witnessed only on 08/24/13 by Lou Grimaldi - witnessing was waived for all other August test dates). If you have any questions or require additional information, please contact Dennis Hartwig at (907) 343-2174 or dennis.hartwig@pxd.com. Sincerely, Vern Johnson Drilling and Completions Manager - Alaska Oooguruk Development Proj* • DW-12010-2011 Annual Performance Report October 29, 2013 Page 3 Enclosures: Attachment 1: DW-1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals Attachment 3: Waste Stream Summary Attachment 4(a) - 4(g): MIT -IA, conducted January 2013 Attachment 5(a) - 5(m): MIT -IA, conducted August 2013 Attachment 6: Pressure Plot of Injection Data 9 Attachment 1 0 Date Average Injection Rate (bbl/min)F Average Injection Pressure (psi)WH Average Temperature ('F) Maximum Injection Rate (bbl/min) Maximum Injection Pressure (psi) Minimum Injection Pressure (psi) 1-Oct-12 0.00 0 0 0.00 f1: 0' 2-Oct-12 4.03 1,906 69 5.82 2,284 1,695 3-Oct-12 4.94 2,081 63 5.83 Z243 1,734'. 4-Oct-12 5.53 2,078 51 5.82 2,223 1,719 5-Oct-12 4.76 2,073 63 5.82 21285 " 1,662 6-Oct-12 0.00 0 0 0.00 0 0 7-Oct-12 4.64 2,065 , 73, 5.82 2,243 1,708 8-Oct-12 4.44 2,030 57 5.81 2,217 1,672 9-Oct-12 , 5.38 2,088 , 51 , 5.80 " 2,259 :. 1,747 10-Oct 12; 4.57 2,100 66 5.68 2,288 1,679 11-Oct-12 5.54 ;2,097 64 5.82 2,237 e, 1,841' 12-Oct42 4.97 2,087 60 5.81 2,283 1,705 13-Oct-12 5.28 2,106 56 5.81 2,282 1,765 14-Oct-12 5.10 2,088 65 5.84 2,260 1,781 15-Oct-12 . " 5.25 P 2,097 61 5.81 .: 2,266 1,788 16-Oct-12 4.18 1,844 75 5.82 2,349 1,515 17-Oct-12 4.53 2,038 72 5.83 2„367 1,68 18-Oct-12 4.55 2,023 72 5.81 2,344 1,724 19-Oct-12 : 5.01 2,117 61 : 5.82 2,316 . 1,784 20-Oct=12 4.53 2,042 65 5.82 2,301 1,781 21:-Oct-12 ; , 4.4Q „ 1,9$4 : 69 5.81 " . . 2,322 - 1,765 22-Oct-12 4.65 2,074 73 5.86 2,300 1,735 23-Oct12 4,45 2,105 - 70 5.79 µ 2,342 ,: 1,76C1 24-Oct 4.41 2,119 76 5.82 2,345 1,758 25-Oct-12 ' 430 2,101 78 5.82 2,369 1,760 26-Oct12 4.45 2,068 74 5.82 2,372 1,762 27-Oct-12 5.03 ' 2,207 63 5.82 2,388 1,743 28-Oct-12- 4.68 2,149 69 5.81 2,385 1,762 29=Oct-12. 5.03 2,225 64 5.81 2,368 1,818' 30-Oct12 4.94 2,220 67 5.86 2,349 1,790 31-Oct-12 4.59 2,276: 72 5.82 2*725 1,76 1=Nov-12 5.25 2,281 61 5.81 2,398 0 2-Nov-12 4.81 2,188 57 5.81 . Z,331 1,905 3-Nov-12 4.69 2,123 60 5.82 2,310 1,770 4-Nov-12 4.71 , 2,129 62 5.80 2,318,1,838' S-Nov-12 4.64 2,089 66 5.92 2,373 1,809 6-Nov-12 5.1`3 - 2,178 > 61 5.92 : 2,373 ` 1,761' 7'-Nov-12 5.05 2,198 63 5.84 2,356 1,756 8-Nov-12 4.73 2,146 63 5.78 2,355. 1,846 9-Nov-12 4.77 2,172 63 5.79 2,353 1,799 10'-Nov-12 . 5.1`3 - 2,163, 60 5.84-- 2,354 ' 1,668, 11-Nov-12 4.691 2,0411 71 5.79 2,372 15583 12-Nov-12 511 2,199 78 580 2'315 1793 Page 1 of 8 • Attachment 1 0 13-Nov-12; 5.40 2,1991 56 5.80 2,353 1,781 14-Nov-12 4.98 2,1741, 61 5.85 2,353 " 1,762 15-Nov-12 4.91 2,190 61 5.80 2,278 1,798 16-Nov-12 " 4.22 1,904 68 5.80', 2,357 1,526 17-Nov-12 3.87 1,901 70 4.01 2,278 1,558 18-Nov-12 .. 4.19 2,106 " ' 64 5.79 2,349 1,817 19'-Nov-12 5.37 2,245 59 5.79 2,318 1,971 20-Nov-12 4.76 2,130 64 5.79,' - 2,353 . 1,893 21'-Nov-12 5.52 2,203 51 5.83 2,300 1,778 22-Nov-12 4.85 2,108 61 5.81 2,329 1,829" 23-Nov-12 4.63 2,132 67 5.80 2,353 1,791 24-Nov-1.2 4.62 2,151 61 5.80 : 2,31R 1,812. 25-Nov-12 4.98 2,200 61 5.83 2,370 1,931 26-Nov-12 4,71 " 2,204 62 5.79 2,362 27-Nov-12' 5.20 2,218 59 5.80 2,361 1,820 28-Nov=12 : 5 38 2,219 58 5.80 , 2,361 1,781> 29'-Nov-12 4.85 2,154 61 5.97 2,362 1,814 30-Nov-12 4.78 2,167 - 67 5.80 . ` 2,371 - 0 1`-Dec 12 4.84 2,140 65 5.82 2,372 1,832 2=Dec712 ' 4.68 2,189 65 5.85 " 2,391 : 1,802 3'-Dec-12 5.34 2,260 58 5.84 2,387 1,797 4'-Dec42 4.96 ; , 2,239 - 62 5.83 " 2,391 1,834 5-Dec12 4.44 2,257 68 5.76 2,387 1,865 6-Dec12 4,801, `. 2,248 63 . 5.77 .," ' 2,383 = 1,80 7-Dec:12 4.30 2,198 64 5.83 2,376 1,934 8'-bec-12 . ' 4.87 2,203 : 55' 5.78 2,362 1,940 5-Dec-12' 5.23 2,235 52 5.78 2,318 1,806 10-Dec42 ; 5.39 2,233 55 5.78 ; 2,364 1,781' 11-Dee-12 4.45 2,199 60 5.79 2,820 1,780 12-Dee-12 4.81 2,183 61 5.78 " 2,374 1,966 13-Dec-12 4.32 2,095 59 5.87 2,387 1,832 14-Dec-12 .. 4.38 " 2,128 59 . 5.78 . 2,407 ° . 1,879 15-Dec-12 4.22 2,165 59 5.78 2,417 1,857 16-Dec-12 ° 4WL 2,147"; 68 5.79 2,443 1,923 17-Dec-12 4.37 2,220 57 5.78 2,433 1,870 18-Dec12 - 3.99 2,255 55 5.78 - 2,415 1,947' 19=Dec12 3.98 2,269 58 5.80 2,397 1,892 20-Dec12 " 4.37 2,269 56 " 5.81 21447 ` 2,000 21-Dec-12 4.62 2,324 52 5.92 2,450 1,915 22-Dec-12 4.25 2,227 61 5.791 21448 1,987 23-Dec-12 4.27 2,238 55 5.79 2,468 2,041 24-Dec12 4.77 2,291 56 = 5.80 2,482 1,94 25-Dec-12 4.89 2,309 55 5.78 2,490 1,932 26-Dec12 : 4.95 2,332 53 : 5.79 - 2,491' 1,931' 27-Dec-12 4.86 2,334 55 5.78 2,483 1,895 28-Dec-12 4.42, 2,268 60 579 2,493 2,003 29-Dec-12 4.171 2,2631 57 5.80 2,491 1,970 Page 2 of 8 • Attachment 1 0 30-Dec-12 4..88 2,350 53 5.80 2,499 1,987' 31-Dec-12 4.69 2,291 56 5.78 2,501 1,896 1-Jan-13 5.33 2,415 50, 5.76 2,494 2,025'. 2-Jan-13 5.05 2,409 55 5.81 2,491 1,919 3-Jan-13 4.62 2,382 52 578 2,456 1,98 4-Jan-13 3.71 2,4281 54 4.03 2,757 1,837 5-Jan-13 3.77 2,382 56 3.99 " 2,450 2,044 6-Jan-13 3.68 2,352 52 4.00 2,441 2,089 7-Jan-13 3.79 2,220 58 408 ' 2,445 1690 8-Jan-13 3.75 2,166 64 4.02 2,440 1,759 9-Jan-13 " 3.79 '° 2,266 67 4.07 2,478 ' 1,910 10-Jan-13 4.35 2,096 62 5.76 2,491 1,575 11-Jah=13 5.04 2;262 54,5.77 2,502 ' 1,58€ 12-Jan-13 4.79 2,189 63 5.83 2,489 1,748 13-Jan-13 ° 4.90 2,374 ,' 51 ' 5.76 2,496 1,822` 14-Jan-13 5.12 2,388 50 5.76 2,487 1,819 15-Jan-13 : 4.48 2,152 "; 63 5.77' 2,480 1,777 16-Jan-13 5.00 2,358 54 5.84 2,489 2,062 4.64 2,268 . 58 6.76 . 2,495 1,856 18-Jan-13 4.66 2,268 58 5.78 2,504 1,836 19-Jan-13 " 4.62 ; 2,294 61 5.85 2,562 1,715 20-Jan-13 4.86 2,414 54 5.77 2,573 1,744 21-Jan-13 4.83 ;427 54 5.76: 2,561 " 2,15 22-Jan-13, 4.80 2,426 54 5.77 2,539 1,929 23-Jan43 4.66 ":-: 2,426 =: 58 ... . 5.78 ` 2,538 2,15 24 Jan-13° 5.23 2,444 50 5.80 2,530 2,048 25-Jan-13 ` . 4.67 °2,237 63 5.81 ; Z531 '1,893 26-Jan-13 5.34 2,448 50 5.80 2,530 1,970 7-Jan-13 : 4.77 2,386 54 ° 5.89 2,531' 2,101i 28Jan-13 5.34 2,414 49 5.79 2,484 1,965 29=Jan-13 5.03 2,385 55 5.82 2,490 2,036,. 30-Jan-13 5.32 2,414 49 5.79 2,494 2,010 31-Jan-13 5.22 Z400 50 579 " 2,488 1,952 1-Feb-13' 4.50 2,369 52 5.80 2,516 2,046 2-Feb-13 5.36 2,413 49 5.79 2,488: 1,994 3-Feb43; 4.77 2,391 52 5.83 2,486 2,019 4-Feb-13 t'" 4.41 " 2,390 61 5.79 : 2,492 ` ": 1,998. 5-Feb-13 4.06 2,363 49 4.27 2,424 2,049 6-Feb-13 " 4.95 2,400 52 5.86 2,493 2,010. 7-Feb-13 5.35 2,410 52 5.77 2,491 1,959 8-Feb-13 4.87 , 2,358 ' 57 5.79 2,500 1,985 9-Feb-13 4.67 2,334 65 5.78 2,505 2,004 10-Feb-13 5 20 - 2,412 58 5.78 2,508 1,962 11-Feb-13 4.65 2,371 66 5.80 2,509 2,057 12-F6-13 5.40 2,432 56 5.80 2,4751, 2,094 13-Feb-13, 4.61 2,396 65 5.79 2,5171 2,064 14-Feb-13 " 5.17 2,433 58 . 5.79 2,481 2,033 Page 3 of 8 • Attachment 1 • 15-Feb-13 5.18 2,416 57 5.79 2,507 1,997 16-Feb-13 4.68 2,3481 64 5.80 2,504 2,047 17-Feb-13 5.24 2,421 57 5.80 2,515 2,015 18-Feb-13 4.76 2,3731, 62 5.80 2,519 2,069 19-Feb-13 4.72 2,267 62 5.82 2,502 1,763 20-Feb-13 428 2,355 60 579 , 2,491` " 2,008 21-Feb43 4.74 2,277 62 5.82 2,523 1,709 22-Feb-13 4.68 < 2,308 65 5.81 2,521 1,869 23-Feb-13 4.46 2,261 69 5.80 2,540 1,972 24-Feb-13 3.91 2,257 ' 79 5.81 "' 2,541 `. 1,963' 25=Feb-13 4.82 2,378 64 5.81 2,526 2,095 26-Feb-13 " 4.44 2,200 67 5.83 2,53W 1,615 27-Feb-13 4.97 2,407 61 5.79 2,519 1,882 28-Feb-13 4.48 2,189 71 5.82 2,538 1,652 1-Mar-13 4.40 2,222 72 5.84 2,556 1,789 2-Mar-13 4.32 , 2,008 77 " 5.82 2,605 1,593 3'-Mar-13' 5.25 2,463 56 5.80 2,532 2,016 4-Mar-13 . 3.10 2,340 59 , 5.78 "" . 2,536 "" 1,945' 5-Mar 13, 4.38 2,496 64 5.82 2,767 1,931 6-Mar-13 ' . 4.11 ,, 2,455 70 : 5.82 :: 2,962 ' . ' 1,971` 7-Mar13 4.26 2,427 73 5.82 2,637 2,031 8-Mar-13 , 4.62 ; 2,537 " "' 64, " . 5.81 $.. 2,691 " 2,204 9-Mar.13 4.95 2,531 62 5.86 2,642 2,072 10-Mar413 = , 4.61 , 2,505 , 62 .. '. 5.87 . 2,802 2F11 . 11=Mar 13" 4.01 2,615 68 5.80 3,023 2,274 12-Mar=13 ; 4.47 2,519 67 5.83 . 2,673 - 2;216 13-Mar 13 5.15 2,634 58 5.81 2,767 2,400 14-Mar-13 4.801, 2,575 i . 57 5.81 Z697 21228' 15-Mar-13 3.94 2,580 59 5.78 3,044 2,294 16-Mar43 3.86 2,623 .;" 70 5.78 „ 2,958 " 2,359 17-Mar13 4.71 2,606 59 5.81 2,771 2,270 18-Mac 13 3.80 : 2,610 " 58 . 4.96 .. 3,005 2,294 19-Mar-13 4.12 2,602 60 5.87 2,941 2,372 20-Mar-13 3.74 2,596 57 4.07 2,922 2,310' 21-Mar-13 3.78 2,629 67 4.09 2,914 2,373 22-mar13 3.46 ,, 2,665 71 4.02 2,911 2,30 23-Mar13 3.81 2,654 61 4.03 2,879 2,292 24-Mar-13 3.66 2,692 69 4.12 ' 2,943 : 2,390' 25-Mar-13 3.72 2,520 70 4.05 2,753 2,118 26-Mar-13 3.76 2,491 71 4.07 2,796 " 2,102 27-Mar13: 3.80 2,455 64 4.06 2,854 2,136 28-Mar-13 4.23 = 2,558 71 6.92.2,908 . 2,242 29-Mar-13 4.28 2,533 66 5.80 2,864 2,226 30-Mar-13 4.51 2,447 63 5.85 2,667 2,199 31-Mar-13' 3.81 2,425 68 4.07 2,860 2,176 1-Apr-13 . 4.23 2,498 66 5.79 2,905 ': 0 2-Apr-13 4.351 2,3391 66 5.811 2,585 1,993 Page 4 of 8 • Attachment 1 • 3=Apr-13 4,56 2,411 -: 62 5.87 2,908 2,015 4-Apr-13 4.26 2,455 72 6.08 2,624 2,151 5-Apr-13 3:97.. 2,391 76 5.89 2,893 2,118' 6-Apr-13 3.92 2,352 68 5.79 2,945 1,879 7'-Apr-13 3.67 2,251 64 4.11 ' 2,805 1,929' 8-Apr-13 3.86 2,0611 59 4.14 2,295 1,766 9-Apr-13 3.90 2,059, . 56 4.34 2,231 1,793' 10-Apr-13 4.71 1,988 69 6.04 2,500 1,704 11-Apr-13 3.88 2,001 66 5.81 2,407 1,620' 12'-Apr-13 3.84 1,975 62 4.07 2,139 1,630 13'-Apr-13 . 3.84 .... 1,965 ' ; 55 4.14 2,054 . 1,716 14-Apr-13 3.82 1,869 52 4.07 1,990 1,659 15-Apr-13 ,_ 4.29 1,886 . 67 5.85 : 2,092 1,614 16-Apr 13 5.00 1,925 61 5.89 2,151 1,655 17-Apr-13 ` ' 3.86 . 2,116 65 5.80' 2,645 1,715 18-Apr-13 3.43 2,282 61 5.81 2,693 1,602 19-Apr-13 3.72 2,374 70 5.82 ~ 2,676 1,854 20-Apr13 3.99 2,337 75 5.81 2,644 1,733 21-Apr-13 4,.41 : 2,316 71 5.80 2,722 1,63 22-Apr-1 , 4.46 2,049 75 5.82 2,416 1,549 23-Apr-13 4,2 2,199. 76 -.. 519 2,687 � 1�,820 24-Apr-13 4.20 2,435 70 5.82 2,640 1,926 25--Apr-13 4.10 2;390 ; °; 69 5.81 2,656 : 1,90E 26-Apr-13' 4.26 2,192 70 5.82 2,441 1,898 27 Apv=13 3:76 ; : 2,312 .-" 68 " "... 4.04 ; .. 2,795 . , . " 2,0 1 28-W43 3.57 2,217 69 4.05 2,612 2,082 29-Apr-13 3.54 2,277 ... 6811, 4.49 =. 2,687 2,07' 30-Apr-13' 3.51 2,270 72 4.51 2,681 2,085 1-May-13 3.74 . ; 2,235 67 4.66 2,4071 2,05 2-May-13 3.79 2,221 66 4.55 2,410 1,962 3-May-13 3.53 2,316 76 4.63 ` 2,654 1,91 t 4-May-13 3.68 2,454 66 4.55 2,725 2,008 S-May-13 3.65 2,320,1 62 4.21 " 2,452 . 1,962 6-May-13 3.43 2,514 81 4.16 2,821 2,092 7` May-13 3.50. 2,510 .: 78 4.07 : 2,795 2,172,. 8-May-13" 3.43 2,372 63 4.06 2,503 2,225 9-May-13 3.67 :. 2,393: 60 4.11 2,472,1 2,214 10-May-13 3.51 2,389 60 4.23 2,812 2,183 11-May-13 3.65 ", 2,440 . 59 � . � 4.05 2,715 �� - 2,294 12-May-13' 3.40 2,520 57 4.02 2,724 2,331 13-May-13 : IT ` 2,427 ' 65 4.03 ` 2,576 2,125 14-May-13 3.79 2,473 58 4.06 2,806 2,190 15-May-13 3.83 ; 2,437 58 4.06 2,790, 2,273 16-May-13 3.84 2,359 59 4.06 2,462 2,249 17'-May-13 3.82 2,296 63 4.05 2,449 " 2,136 18=May-13 3.68 2,297 71 4.13 2,776 2,065 19-May-13., 3.61 2,397 59 4.081 2,842 2,065 Page 5 of 8 • Attachment 1 • 20-May-13 3.85 2,6271 68 4.10 2,850 2,145 21-May-13 3.75 , 2,385 65 " 4.12 2,812 2,065 22-May-13 3.83 2,353 65 4.09 2,548 1,920 23-May-13 3.90 2,407 59 4.11 2,551 " 2,101, 24=May-13 3.85 2,470 56 4.11 2,549 1,745 25-May-13 3.86 2,4831 52 4.10 2,532 2,248 26-May-13 3.60 2,461 66 4.18 2,541 2,286 27-May-13 3.90 2,449 62 4.15 2,530 2,290 28-May-13 3.90 2,470 57 4.10 2,533 2,345 29=May-13 . 3.85 ; 2,441 59 4.05 " 2,557 2,297 30-May-13 3.81 2,418 78 4.07 2,575 2,249 31-May-13 3.76., 2,426 61 4.20 " 2,795 1,920 1-Jun-13 4.58 2,503 62 5.95 2,595 2,242 2-Jun-13 4.031, 21450 59 5.82 2,511' " 2,251 3-Jun-13 4.46 2,430 55 5.84 2,564 2,045 4-Jun-13 3.84 " 2;458 57 4.04 2,528 2,281 5-Jun,13 3.78 2,406 57 4.05 2,519 2,055 6-Jun-13 `" 3.87 , ' '21410 54 " 4.01 2,536 > 2,293 7-Jun-13 3.85 2,4231 69 4.06 2,527 2,186 8-Jun-13 3.89 <. 2,404 54 " 4.04 : 2,537 2,324 9-Jun-13 3.79 2,426 58 4.17 2,549 2,259 10-Jun-13 3.55 " Z459 61 6.09 - 2,614 . 2;303'. 111un-13 4.68 2,499 58 5.97 2,643 2,291 12-Jun-13 `" 5.11 : 2,547 73 5.83 2,625 2,407 13-tun-13 4.59 2,438 65 5.81 2,576 2,252 14-Jun43 : ` 4.70 ": 2,472 -, 59 5.86. " 2,574 2,312 15-Jun-13 3.91 2,432 61 5.80 2,576 2,265 16-Jun-13 ; 3.76 = 2,435 59 5.80 " 2,558 ;r 2,275 17-Jun-13 3.74 2,388 56 4.04 2,514 2,243 18Jun-13 " 4.80 2,451 - 58 5.87 2,574 2,290' 19-1un-13' 3.84 2,437 58 5.81 2,578 2,278 20-Jun-13 4.48:. 2,413 63 5.81 2,561' 2,210 21-Jun-13 3.65 2,406 62 5.81 2,576 2,228 224un-13 = 0.55 2,256' 86 " 0.57 <. 2,340 2,181 23Jun-13 3.50 2,338 60 5.79 2,501 2,159 24-Jun-13 3.96 2,356. 47' 4.04E 2,436 2,28CY 25-Jun-13' 3.47 2,415 63 5.81 2,516 2,175 26-1un-13 "= 0.00 0 11;. 0'' 0.00 0 0 271un43 5.02 2,415 56 5.86 2,507 2,075 28-Jun-13.° 3.42 2,438 53 4.35 2,792 2,207 29-Jun-13 3.90 2,410 74 4.38 2,508 2,255 30-Jun-13 0.0M," 0 0 0.00 0 ; ' 0 1-Jut-13 3.81 2,344 66 4.16 2,472 2,133 2-Jut-13 " 3.98 " 2,380 51 4.37 2,510,Z307' 3-Jul-13 4.25 2,4181 56 5.80 2,588 2,270 4-Jul-13 " 4.95 : 2,4351 69 5.80 , 2,528 " 2,310 5-Jul-13' 5.51 2,3871 64 5.82 2,502 2,181 Page 6 of 8 • Attachment 1 • 6-Jul-13 5.25 2,387 57 5.80', 2,523 2,155' 7-Jul-13 0.00 0 0 0.00 0 0 8-Jul-13 . " 4.80„ 2,391 65 . 5.80 2,513 2,179' 9-Jul-13" 5.19 2,411 54 5.82 2,530 2,238 10-Jul-13: 5.26 2,412 53. 5..86, 2,525 2,215 11-Jul-13 0.00 0 0 0.00 0 0 12-Jul-13 3.77 2,39011, 66 4.01 2,509.2,108 13-Jul-13' 4.48 2,429 61 5.80 2,530 2,245 14 Jul-13 3.90 . 2,350 56 5.83 2,556 2,212 15-Jul-13 3.23 2,572 62 5.81 2,853 2,249 16-Jut-13 : 3.13 "; 2,369 59 4.02 . 2,464 : 2,261' 17-Jul-13 3.74 2,391 64 4.02 2,470 2,312 18-Jul-13 0.00 0 0 ' . 0.00- 0 . 0 19-Jul-13 4.56 2,394 77 5.85 2,500 2,091 20-Jul-13 4.51 2,420. 62 5.87 2,498: 2,243 21-Jul-13 4.54 2,412 60 5.85 2,549 2,232 22-Jul-13 - 4.72 ; 2,375 68 5.79 2,462' : " 2,227 23-Jut-13 2.47 2,379 72 5.78 2,920 2,116 Z4-Jul-13 0.00, 0". 0 0.00 ` U 25-Jul-13 0.00 0 0 0.00 0 0 26-Jul-13 " 0.00 .:,. 0 .. . F 0 0.00 :- " , ; (� .; " 0 27-Jul-13 5.11 2,338 83 5.90 2,506 2,188 28-Jul-13 0:00 0 ;, 0 0.00 0 a. 29-Jul-13 0.00 0 0 0.00 0 0 30-Jul-1 0.00 .. F - 0 ... ' ". b.. �.. 0.00 .. .. f'0, 31=Ju1*13 0.00 0 0 0.00 0 0 1`-Aug-13 .° ` 0.00 0 0 .; 0.00 0 f 2'-Aug-13 0.00 0 0 0.00 0 0 3`-Aug-13 : 0.00 0-1 0 0.00" 0 : ... - 0, 4-Aug-13 0.00 0 0 0.00 0 0 5-Aug-13 0.00,'- 0- 0 0.00 ' 0 , 5 6-Aug-13 0.00 0 0 0.00 0 0 7-Aug-13 ., 0.00 0 0 0.00 8-Aug-13 0.00 0 0 0.00 0 0 9-Aug-13 0.00 , a 0 0.00 0 0 10-Aug-13 3.91 2,147 83 5.85 2,395 1,958 11-Aug-13 3.78 . 2,243 64 4.12 2,355 ' 2,116' 12-Aug-13 4.08 2,282 60 5.81 2,391 2,200 13-Aug-13 4.64 2,282.. 56 5.81 2,394 2,130 14-Aug-13 4.51 2,176 64 5.82 2,397 2,016 15'-Aug-13 " . 4.68 2,263 ` 64 5.86 2,415 ' 2,104 16-Aug-13 5.25 2,323 56 5.87 2,411 2,222 17-Aug-13 4.71 2,181 . 63 5.84 ' 2,437 1,808 18-Aug-13' 3.38 2,163 65 5.87 2,779 1,704 19-Aug-13 3.88 2,304 66 5.83, 2,564: 1,867' 2C1-Aug-13 4.521 2,2361 68 5.841 2,444 1,960 21-Aug 13 3.60 . 2,250 ' 49 5.81 2,429 , 2,000' Page 7 of 8 • Attachment 1 • 22-Aug-13 4.93 2,2811 63 5.83 2,439 2,061 23-Aug-13 4.53 2,114 " 67 5.85 2,457 1,724 24-Aug-13; 3.14 2,026 66 5.85 2,438 1,631 25-Aug-13 ,. 3.98 `" . 2,037 70 5.85 2,455 1,327 26-Aug-13 3.81 2,040 67 5.94 2,456 1,577 27-Aug-13 2.37 2,117 55 4.38 2,401 1,794 28-Aug-13 3.61 2,274 69 5.87 2,710 1,836 29-Aug43 4.16 , 2,325 60 5:83 2,422 2,209' 30-Aug-13' 4.06 2,378 69 5.85 2,848 2,090 31-Aug713 ,.. 4.09 - 2,166 66 ": 5.95 ; 2,451 1-Sep-13' 4.86 2,316 59 5.87 2,452 2,141 2-Sep-13 4.56 . 2,222 62 5.87 2,431 - 21061, 3-Sep-13: 5.14 2,365 59 5.92 2,464 2,249 4-Sep-13 4.78 . 2,158 62 584 2,456 1,747 5-Sep-13 4.75 2,241 61 5.82 2,460 1,784 6-Sep-13 3.80 21243 69 4.05 2,435 1,9E13 7-Sep7-13 5.33 2,330 56 5.83 2,446 2,071 8-Sep-13 . 4.45 : 2,137 71 5.85 ` 2,465 ' 1,810 9-Sep-13 3.99 1,920 76 6.01 2,483 1,514 10-Sep-13 4.41 2,007 711, 5.86 2,449 1,501, 11-Sep-13 4.49 2,294 67 5.82 2,457 2,024 12-Sep-13 _. 4.61 ; 2,218 61 5.85 2,457 ' , 1,8$1' 13-Sep-13`. 4.68 2,233 65 5.90 2,485 1,974 14-Sep-13 . 4.34 , 2,212 -; " . ` 67 5.84 2,474 1,966 15-Sep-13'° 3.94 2,278 49 5.81 2,328 2,088 16-Sep!13 ; :. 4.56 2,237 65 5.83 ' 2,,Q 1,849 17-Sep-13 4.66 2,266 62 5.94 2,482 1,967 18-Sep-13 4.53 " 2256, 66 5.82 2,490 : 2,054'. 19-Sep-13 4.18 2,339 55 5.81 2,499 2,053 20-Sep-13 3.75 = 2,311 : 64 .. 4.05 2,478 2,025 21-Sep-13' 3.58 2,318 60 4.06 2,445 2,007 22-Sep-13 , 3.83 ` 2,334,52 4.01 2,417 : .' 2,050 23-Sep-13' 3.79 2,348 61 4.15 2,457 2,053 24-Sep-13 :' 3.83 2,351 54: 3.99 2,440 = 2,088 25-Sep-13 4.84 2,415 61 5.91 2,507 1,999 26-Sep-13 5.35 : , 2,373 ;: , 52 5.83 2,491 2,071 27-Sep-13' 5.19 2,390 58 5.93 2,488 1,989 28-Sep-13 . 0.00 . 0 - -0 - 0.00 . 0 0' 29-Sep-13 4.76 2,398 63 5.86 2,484 2,020 30-Sep-13 5.20 2,357 ; 54 5.79 ;. 2,445 :. 2,089; Page 8 of 8 Attachment 2:anthly Infection Totals and WA Stream Summary Monthly Injection Totals Month Volume of Injected Fluid (BBLS) October 2012 49930 November 2012 36520 December 2012 57497 January 2013 39303 February 2013 33662 March 2013 69130 April 2013 95637 May 2013 67511 June 2013 32887 July 2013 21615 August 2013 31417 September 2013 38841 Page 1 of 1 Attatment 3 - Waste Streams Sufthary Physical, Chemical, and Other Relevant Characteristics of the Injected Fluids M • Incidental non -hazardous wastes generated by module operations & - Wash water, seawater used Waste characterization sampling Utility modules sump maintenance for drilling mud make-up, potable water chemical completed and verified not RCRA- fluids • Incidental equipment leaks additives. Process control is hazardous — Confirmation sample • Additives for Reverse Osmosis & potable strictly maintained collected 01/15/13 water systems Waste characterization sampling Glycol/heat exchange • Vehicles & equipment (antifreeze) Glycol (MEG, DEG, TEG, completed and verified not RCRA- media Module and facility heating and cooling propylene) hazardous — Generator knowledge systems used Non-exempt spill • Fluids recovered from cleanup of non- Water, snow, gravel, with Waste characterization sampling completed and verified not RCRA- clean-up exempt spills hydrocarbon or chemical hazardous — Confirmation samples . Spill impacted gravel or snow products collected 10/17/12 and 03/06/13 Water, glycol, possible Waste characterization sampling Hydrotest fluid • Pressure test new or non-exempt process product residual in existing completed and verified not RCRA- (water or glycol only) lines, vessels lines, traces of chlorine or hazardous — Generator knowledge other biocide used Not injected year to date, fluids used Boiler blowdown • Rig or production facility boilers Water for drilling mud make-up water Off spec product • Products spilled, out -dated or no longer Varies — MSDSs reviewed Not injected year to date acceptable for original purpose Contained snow/ • Outdoor containment around fuel and Water, possible traces of Waste characterization sampling completed and verified not RCRA- ponded water chemical storage tanks hydrocarbon or chemicals if hazardous — Generator knowledge . Depressions on or between pads & roads there have been spills used Routine verification sampling • Motor oil conducted confirm not RCRA- Lubrication oil • Transmission fluid Hydrocarbonstwater mixes — hazardous —Typically sent to • Hydraulic oils hydrocarbon or offsite recycle • Internal or external washdown of skids, Non-exempt facility modules • Equipment cleaning (using non- Water, possible traces of Waste characterization sampling completed and verified not RCRA- wash water hazardous detergents or degreasers) hydrocarbon, chemicals, detergent hazardous — Generator knowledge • Residues removed from RCRA-empty used containers Waste characterization sampling Incinerator ash • Trash and camp waste Particulates/RCRA metals completed and verified not RCRA- hazardous — Confirmation sample 9 Sewage sludge collected 07/15/13 Domestic • Camp wastewater treatment plant(s) and Water, soap residuals, human NPDES permitted facility, RCRA wastewater/ sludge site enviro-vacs waste Exempt Waste characterization sampling Reverse osmosis • Saline concentrate from reverse osmosis completed and verified not RCRA- concentrate/seawater Process for making potable water from Saline water hazardous — Confirmation sample seawater collected 04/28/13 Notes: 1. Similar wastes may be RCRA exempt, depending on waste -generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 Attachment 4(a) United States Environmental Protection Agency Region 10 i1Mi' 1200 Sixth Avenue. Suite 900 Seattle, WA 98101 Mir Culler - (2fNt) 553.1673 e-mail: cutler,thor+ i epa.gm MECHANICAL INTEGRITY TEST (MIT) FORM Facilitv well Permit No. PTD No. Pioneer- Oooguruk Unit ODSDW 01-44 AK-11009-A 207-140 Injector all' TYpe I test 7)pc Test Date Class I I T X IA I Sid. Annular Pressure I"est (SAPT) 1;27i2013 Req`d Test Fluid T%pe(%) used to Packer Depth In. Test Interval /Comments Presssure(psill test TVD) 3.500 Diesel 1 5.035' One Year Cycle Record all Wellhead Pressures bcfi)m and during Test Nett whether well is on injection or SI during lest Icon iniewtion, note injection rate, injeclum pressure and injection tluid temperature Note colmne ol•diesel 50:50 methanoVglycol pumped in annulus during test T E S T START TIME: + € RECORDED PRESSURES (PSI) RESULT PIF it ,-, PRE: NIIT INITIAL 15 Nil 30 MIN 45 MIN 60 SIIN TUBING 2A l, l & INNEK ANNULUS Li a = 1 •: OUTER ANNULUS L 1 COMMFNTS:- , T E S START TIME: RECORDED PRESSURES (PSI) RESULT PASS' PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING T INNER ANNULUS IAII. OUTER ANNULUS 2 01MMI'N'IS: T E S T START TIME: RECORDED PRESSURES (PSI) RESULT PASS I°`AII PRE NII I INITIAL 15 MIN 30 MIN 415 MIN 60 AIIN TUBING INNER ANNULUS OU'1'E:R ANNULUS 3 Ct>MM1 N'I:ti: MISC COMMENTS NOII_ Pressure muss show stabilizing tendency i i IoLd 1wessure loss must he less than 10 '3: at end of 30 minute test 2) 1're sure loss in last I S minutes must he less than 33% of total loss Stan Nit over if: 11 1 ol.'al less exceeds 10 ^, 21 loss during lust 15 tninuic period = or jfl"ti, of Ions doting first I i tmnute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 L� C� -- E-mail this M I7 'test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep - Thor Cutler i-� .` t t it Attachment 4(b) _ hi IT OUS IDw 1.44 y4 n•,f,ybi 7[p 1l 11� +U:A ;XMR—fI , _. , 1;, 'yr las,d.s� Nwtn Lw. (ib '.rb 1i+r 14wn 4AYr. T—Dow S.—Sa.n Q wLii+0.3t U<1061.Do VNi M NIYriA w 0 Sl00-..']215l 12112,$S ':0.'wox 11 5AX Bra Uti001 ieeVll - n1YYU M C vlp •Vlft/llY1•LY O tffJC Y N 1/27/2013 12:32:56 PM 0 Attachment 4(c) • 1 - _. TAP - miT oos vw %-jA T. •nt-. CM�Yir N.6. y... f.q �Ms 0 jj01_uMl MIT• m.91.4 :. T mmo _=s 1/27/2013 12:30:44 PM x"i'r :P•"N M. ffi..— IY MM,f .v I me I"•;, ';rl� G,Tn M'IV 31,5m1Aay. N%n AA.AXI Vr..97 R W Attachment 4(d) O000uruk Wellwork Supervisor From: Noble. Robert C (DOA) <bob.noble@alaska.gov> Sent: Thursday, January 24, 2013 5:41 PM To: Abbott, Tom; DOA AOGCC Prudhoe Bay Subject: Re: AOGCC Test Witness Notification Request: MIT, Oooguruk ODS DW 1-44 Tom If its going to be witnessed by EPA reps I will waive witness. Bob Noble From: Tom Abbott fmailto:Tom.AbbottO xd.coml Sent: Thursday, January 24, 2013 01:56 PM To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: MIT, Oooguruk ODS DW 1-44 X uestion Answer Type of Test Requested: MIT Requested Time for 01-27-2013 11:00 AM Inspection Location Oooguruk ODS DW 1-44 Name Tom Abbott E-mail Tom. Abbott(if�pxd.cum Phone Number (907) 670-6602 Company Pioneer Nat'l Resources Planning our annual MITIA on our disposal well. Test will be Other Information: witnessed by EPA (Thor Cutler & Taled Saed). Please let me know if you would also like to witness the test. Submission ID: 224877414431250699 i 7 • A a Environmental Protection Agency +,,, do Otrue of compliance arW Enforcement Thor Cutler, Environmental Scientist CPG # 8475, LG, LHG, LEG 1200 Sixth Avenue, Suile 900 Tel: 206-553-1673 OCE-127 FAX: 206w3-8509 Seattle, WA 96101 Email: cutler.thor@epa,gov Talib Syed, R.E Petroleum Engineer TSA, Inc. Consulting Petroleum and Environmental Engineers 6551 S Revere Pkwy Suite 215 Centennial, CO 80111 Tel 303.969.0685 talibs@ecentral,com CeW 720.877 1272 www.talibsyed-assoc.com Fax: 303,969.0838 Attachment 4(e) • Ottachment 4 (f ) NOTICE OF INSPECI iON I .S Emirotimcnial Pro(ecttoo Agency Phone 12061 ji 1-167,t Ciflice otCompliauce and l nliorc•ealem Attn: Thor Cutler i(K E-127r (rounel Water I'rolcetiorr l'nil 1 "IC Program 1210 Sixth Avenue Suite this) Seattle. WA 9SII)1 Bros \ante fi Address: EPA FIC Permit rr A L LI Ci Inspector Name & Signature — — — Thor Cutlerffinurth) Makers IL --Date urentr} government Contractor Print Name & Signature: INSPEC'110% I"YPI: Clunpliance(Roulinel V111,� fcstir>glsaniplin�**Closure NOTICE OF INSPECTION IS IIERERV I;IVEN ACCORDING 1-0 SECTION I445 till OF THE SAFE DRINKING WATER ACT 142 U.S.C. 31NI F et seq.) kl-ASt1N FOR INSPECTION: Fot the purpose of insivctim-, records, files. papers. processes. control, and I"acililies..mdlor ohfaiuing samples to tictcnnine whether the person suhleci to an applicahte tinder+round injection control program liar acted nr is acting, in compliance with file Sale I)rinkinp 1\:urr Act and an% applicahle permit or rule Text ,,t142 I ".S,S .AM-l--t th1 Section !� 1S tilt of the Sate Urinkun NN';uer Act tbij 1 l Except a., provided in paragraph t's. the Administrator. or representa(kes tit the Administrnor dull assigned by him. upon presenting, appropriate credcntj;tl. ;old ri wrjnen notice lu any supplier of water or +,Iher person subject h, sA l .t rralionul prinrny drinking seater re,;ulalion prascribed under section I l I' l li i ;ut aplrhrahlc undcrvromtd injection euntrtol pro ram ur lCl any requurmeni it, monitor an unregulated comarninanl pursuant fo subsection sal. or person in char-e of ame ul the property of suite supplier or other person. is authorved to enter tmti cmablishment. facility. or other properly (it such supplier or other person in order it, determine wfiether such ulppljer or other person has acted or is acting in contpli:mer with this title. including,. for tilt. purpose. inspection. al reason lhle times, of record,. files. papers, processes. controls, and I;K iliiics. or in order to test anyv (eamw of i puhhc wader sy.Iem. including its raw water source. The Administrator or the Controller C tencrd for;ntc represcniatse designated. by eltherl shall have .feces I,er the purpow of andii and vvirlrin;iii,ln is, am rectirdp, reports. ur information of a grantee which are regnired Iu he mainlained under subsecti-in tat „i which ;ire persistent to anv linnlcial ;Issislance under this title. i _' i \,, entry nray he made under Iho first sentence of paragraph (I i man establishment. lacilitt, for other property of water or other person sithiect to a rimiomil primary drinking, water re,mlanwl it the establishment. kicilit}, or other prnpem is locased in a State- which has primacy entAreentern responsihilily tut public walcr systems sinless, hefory written notice tut such entry is made. the Adrinnislr nor im tits representatives notifies, the: Suite a�_cncy ch;irged wish responsibility for sale drinking water it the reason. for such entry. Tire Adminismiior shill. upon a showing by file Sate agency Ihat such elnry will he detrimental to the administration 411 the States program of primary enlurcemeut responsibility. take such showing into consider Lion in determining, whelkter to imike such emry No Stitt•" agency which receive. notice under Ilri, par;rgr ph of in entry proposed to he made unclesparagraph i I i may u.c file inliormation contained in the notice to inl�orin lite person whose properly is prop,scd w he entered of lite prolx,sed entry: and it a State agency so user such ilttn'rnatt011_ notice t s the agcnev under this paragraph is not required until such time as the Administrator dctermincs the ag,ency has prin idcd him salislactrn assurances that it will no longer s„ use information contained in a notice under fhis p:u"ag,raph. Whoever tails or refuses to comply with any iequiremenl of subsection i I ) or to allow the:\dminkirat,r. the Comptroller Ciencral. or representatives of either% toc`irter and Conduct tiny audil ur inspection authorized by suhsecsiirn ills shall he subject to a civil penalty. not to exceed 47.i(X). • Attac&t 4 (g) A Unites Staten `�/' o Environmental Protection Agency Ounce of Enforcement and C urnpliance Assurance (2201 A) CPA-300-F- I 1-006 June 2011 The United States Environmental Protection .Agency provides an array afresources- including work5hops, training sessions. hotlines. websites and guides. to help small businesses understand and comply with federal and state enN°ironmental laws. In addition to helping small businesses understand their environmental obligations and improve compliance. these resources will also help such businesses find cost-etfFective ways to comply through pollution prevention techniques and innovative technologies. EPA's Small Business Websites Small Business Environmental Homepage - www.smallhir-enviroweb.org Small Business Gateway- - w'w,v.epa.gov/smalIbusiness EPA's Small Business Ombudsman - w-,vw.epa.gov+'sbo or 1-800-368-5888 EPA's Compliance Assistance Homepage wwvc.cp,t.g�n compliancy assisance husiness.htnri This page is a eatew-•ay to industry and statute -specific environmental resources. from extensive web -based information to hotlines and compliance assistance specialists. E:Ms Compliance Assistance Centers w mv.assistancecenters.nei F.P.A's Compliance Assistance Centers provide information targeted to industries with marry small businesses. They were developed in partnership with industry. universities and other federal and state agencies. Agriculture ww'vy.epa.4rov'agriculture Automotive Recycling w vvw.ecarcentenoru Automotive Service and Repair vwvyv.tw ��nlink.orz or 1-888-GRN-I .INK Chemical Manufacturing w'ww.che coal I iance.or`g, Construction wwvv.cicacenter.or.,* or 1-734-99a-4911 Education www.campuserc.org Food Processing 1\'w'w. tpeaC.oCL Healthcare www.hercenter.or Local Government www.leean.or_r Metal Finishing wwvv.nrnfrc.org Paints and Coatings www.paintcenter.org Printed Wiring Board Manufacturing vvww'.pvybrc.or_g Printing www'.pneac.org Ports www.portcumpliance.ors L.S. Border Compliance and Import/Export Issues wvw w.bordercentenorg Hotlines, Helplines and Clearinghouses vvvvw.epa.Uov, epahome%hotl ine.htm FPA sponsors many free hotlines and clearinghouses that provide convenient assistance rezardint_, environmental requirements, Some examples are: Antimicrobial Information Hotline info -antimicrobial i,epa.gov or 1-703-308-6411 Clean Air Technology Center (CATC) Info4ine w%k-w.epa eov ttn cats or 1-g 19-541-080 ) Emergence Planning and Community Right -To -Knox Act wwyv.epa.gov 'superf undr resources/ inf center%epera.htm or 1-S00-424-9346 EPA Imported Vehicles and Engines Public Helpline wwvv.epa.tiov'otaq�'imports or 734-214-4100 National Pesticide Information Center yvww.npic.orsi.e&'or 1-800-858-731178 National Response Center Hotline - to repeat oil and hazardous substance spills wwvv.nrc.uscg.mil or 1-800-424-8802 Pollution Prevention Information Clearinghouse i PPIC) vvww epa.eoviopptintr,-ppic or 1-202-566-0799 Safe Drinking Water Hotline vvww.epa.gov: safevvater hotline'inc:x .d. html or 1-800-426-4791 Stratospheric Ozone Protection hotline www.epa.uov'ozone or 1-800-296-1996 0 Attachment 5(a) D. Mechanical Integrity Test of Tubing Hanger Seals and Tree Void — Pressure Chart and EPA MIT form 0 I 3 a 41 Ael 'DEL W 1-4 ri Ln 66 41 41 4-1 /4 < - "V w 10 1 Attachment 5(d) United States Environmental Protection Agency y Region 10 s 1200 Sixth Avenue, Suite 900 �t MqL Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. Pioneer - Oooguruk Unit ODSDW 01-44 AK-1I009-A 207-140 Injector MIT Type Test Type Test Date Class I 8n12013 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) 5,000 Hydraulic Fluid 4,999 1 Others (describe in notes) Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel/50:50 methanol/glycol pumped in annulus during test. T E S T START TIME: 10:00 hrs RECORDED PRESSURES (PSI) RESULT Pass PRE MIT INITIAL 5 MIN 10 MIN Tubing Hanger Seals 0 5160 5160 5160 INNER ANN ULUS n/a n/a n/a n/a OUTER ANNULUS n/a n/a n/a n/a I COMMENTS: 5000psi Test of tubing hanger seals for 10 minutes T E S T START TIME: RECORDED PRESSURES (PSI) RESULT Pass PRE MIT INITIAL 5 MIN 10 MIN Tree Void 0 5160 5160 5170 INNER ANNULUS n/a n/a n/a n/a OUTERANNULUS n/a n/a n/a n/a 2 COMMENTS: 5000psi Test of Tree void for 10 minutes T E S T START TIME: RECORDED PRESSURES (PSI) RESULT PASS/ FAIL PRE MIT INITIAL 15 MIN 30 MIN 1 45 MIN 60 MIN TUBING INNER ANN ULUS OUTER ANNULUS 3 COMMENTS: NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 10 minute test 2) Pressure loss in last 5 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 5 minute period = or > 50% of loss during first 5 minute period Extend test duration to 20 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 0 -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler via Email Correspondence Lou Grimaldi waived witness Rodney Nepzig Attachment 5(e) E. Mechanical Integrity Test of Tubing - Pressure chart and EPA MIT form. M■ • • Attachment 5(g) "'. ' United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. Pioneer - Ooo uruk Unit ODSDW 01-44 AK-1I009-A 207-140 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 8/8/2013 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) 3,500 8.4 ppg seawater 1 4,999 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel/50:50 methanol/glycol pumped in annulus during test. T E S T START TIME: 0430 firs RECORDED PRESSURES (PSI) RESULT Pass PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING 0 3600 3580 3570 3560 3550 INNER ANN ULUS 2050 2300 2290 2275 2260 OUTERANNULUS 0 0 0 0 0 0 1 COMMENTS: 4-1/2" Tubing Test - Well is shut-in during test Mechanical Integrity Test of Tubing with Plug set in tubing below packer at 5,017ft MD T E S T START TIME: RECORDED PRESSURES (PSI) RESULT PRE MIT INITIAL 15 MIN 30 MIN TUBING INNER ANN ULUS OUTER ANNULUS 2 COMMENTS: T E S T START TIME: RECORDED PRESSURES (PSI) RESULT PASS/ FAIL PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING INNER ANN ULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Notified AOGCC for the MIT on tubing and annulus tests via e-amil on 8f7/13 at 1031 firs. AOGCC waived witness on tubing and annulus pressure via e-mail of 8/7/13 at 1035 hrs. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler via Email Correspondence Waived by AOGCC Rep. Rodney Klepzig Attachment 5(h) F. Mechanical Integrity Test of IA - Pressure chart and EPA MIT form. C� • } s 25 i 1 I oo �b o "' b -- r 0 Attachment 5 (j ) United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 ° Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. Pioneer - Ooo uruk Unit ODSDW 01-44 AK-1I009-A 207-140 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 8/8/2013 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval / Comments Presssure (psi) test TVD) 3,500 8.4 ppg seawater 1 4,999 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel/50:50 methanol/glycol pumped in annulus during test. T E S T START TIME: 0730 hrs RECORDED PRESSURES (PSI) RESULT Pass PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING 600 1325 1325 1320 INNER ANN ULUS 0 3700 3680 3670 OUTERANNULUS 0 0 0 0 1 COMMENTS: 4-1/2" x 7" Annulus Test - Well is shut-in during test Mechanical Integrity Test of IA with packer set at 4999ft MD T E S T START TIME: RECORDED PRESSURES (PSI) RESULT INITIAL 15 MIN 30 MIN TUBING INNER ANN ULUS OUTER ANNULUS 2 COMMENTS: T E S T START TIME: RECORDED PRESSURES (PSI) RESULT PASS/ FAIL PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING INNER ANN ULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Notified AOGCC for the MIT on tubing and annulus tests via e-mmil on 817/13 at 1031 hrs. AOGCC waived witness on tubing and annulus pressure via e-mail of 8/7/13 at 1035 hrs. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 — E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler via Email Correspondence Waived by AOGCC Rep. Rodney Klepzig Attachment 5(k) G. Mechanical Integrity Test of IA per AOGCC 24Aug13 - Pressure charts and EPA MIT form. (Y) H N V 00 0 O O �ca • A.11chment 5(m) �iJ ' United States Environmental Protection Agency �Y Region 10 1200 Sixth Avenue, Suite 900 —'' Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. Pioneer - Oooguruk Unit ODSDW 01-44 AK-1I009-A 207-140 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) 8/24/2013 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TyD) 3,500 8.4 ppg seawater 1 4,999 1 One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel/50:50 methanol/glycol pumped in annulus during test. T E S T START TIME: 0430 hrs RECORDED PRESSURES (PSI) RESULT Pass PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING 2399 2400 2285 2282 2279 2276 INNER ANNULUS 8 3705 3700 3702 3704 3704 OUTER ANNULUS 21 31 26 25 25 24 1 COMMENTS: Test conducted after well was back in service approximately 10 days following RWO Injection Interrupted during test, allowed to stabilize and reading taken every 15min, total test 2 hrs. 2.1 bbls of diesel pumped into annulus and 2.1 bbls returned. Avg injection rate 2.86 bpm T E S T START TIME: RECORDED PRESSURES (PSI) RESULT Pass/ Fail PRE MIT INITIAL 15 MIN 30 MIN TUBING INNER ANNULUS OUTER ANNULUS 2 COMMENTS: T E S START TIME: RECORDED PRESSURES (PSI) RESULT PASS/ PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING T INNER ANN ULUS FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler via Email Correspondence Lou Grimaldi Ian Curphy 10/12012 12noonmo 1MUM2 7:54:00 AM 11 AW2012 3:48:00 PM 12/132012 12:27:00 AM 1AS=3 8:21:00 AM 1 /302013 4:15:00 PM 2242013 12:09:00 AM 3f2012013 9.03 00 AM :1 4113f2013 4 57 00 PIJ SAM 3 12:51:00 AM 6/12013 8:45:00 AM 6252013 4:39:00 PM MOW 12:33:00 AM All 92013 2? 1110 i,)A 9Ai2013 4:21:00 PM I I II I 0 0 N lnll I2012 — 12 00 00 "m Q VI 3 1012 ;7201 T 400 MA — 11 !7 Rno 12 I'— - — 3 48. 00 rt.1 l 2n arm z IIIIIIIE l z '�- nn i,1.1 1 k"13 8.21:00 AM 1 JJOM 3 4:15:00 PM 21241M 3 12.09:00 AM MOW T � 9:03:00 AM I �i 41132013 4:57:00 PM 5182013 12:51:00 AM 6/112013 8:45:00 AM WSW 3 4:397.00 PM MOW 3 1233:00 AM 8n3n013 8:27:00 AM 9i W3 4:21:00 PM snn innn U00 2000 2500 30nn 3'XI0 0 0 v to N I IA m I� 1 � A N 1 A O A rF N N O 1-, N rh O m rF ui O N O N V TI X N m v I"F 13 THE STATE °1f�,l�5i<t� GOVERNOR SEAN PARNELL April 30, 2013 Conservation Commission CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3569 Mr. J. Patrick Foley Manager of Land and External Affairs Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Investigation of Improper Diesel Injection at ODSDW 01-44 (PTD 2071400) Disposal Injection Order (DIO) 031.000 Oooguruk Unit Dear Mr. Foley: On March 11, 2013 Pioneer Natural Resources Alaska, Inc (Pioneer) provided the Alaska Oil and Gas Conservation Commission (AOGCC) with a letter following up on a verbal notification provided on March 5, 2013. The letter details the injection of between 44 and 53 bbl of diesel during one waste injection cycle because of a valve being inadvertently left open. Specifically, diesel was pumped at the start of the waste disposal cycle and was not, at the time of this injection, being pumped as freeze protection fluid, a violation of Rule 2 of DIO 31. However, because the diesel, which is generally used as freeze protection fluid for the well, would ultimately have been injected and because the AOGCC is in agreement with Pioneer's proposed corrective actions, at this time the AOGCC does not intend to take enforcement action against Pioneer in connection with this violation. Sincerely, Z- r� Daniel T. eamount, Jr. Commissioner cc: Thor Cutler, USEPA, Region 10 AOGCC Inspectors • • Investigation of Misinjection OLJDW 01-44 April 30, 2013 Page 2 of 2 TION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b). " ltlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 12 0 PIONEER 0 NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277-2700 Fax: (907) 343-2193 March 11, 2013 Chris Wallace Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Oooguruk Unit, Disposal Injection Order No. 31 — Notification Pursuant to Rule 7 Dear Chris: I am writing on behalf of Pioneer Natural Resources Alaska, Inc. ("Pioneer") to formally confirm the verbal notification provided to the Alaska Oil and Gas Conservation Commission ("AOGCC") on March 5, 2013, and the related email exchanges of the same date. As you know, Pioneer is the operator of the Oooguruk Unit and the recipient of the AOGCC's Disposal Injection Order ("DIO") No. 31 (June 19, 2007). This written notification is provided in further compliance with Rule 7 of DIO 31. On March 5, 2013, at approximately 4:05 a.m., up to approximately 44 barrels of diesel product were inadvertently injected into disposal well DW-1 at the Oooguruk Drillsite. Disposal into DW-1 is accomplished by the use of an injection pump (P-6) that is capable of drawing from several different tanks connected to a common header. The normal process consists of the pumping of a sequence of fluids from these tanks, beginning with waste material injected into DW-1, followed by a seawater flush, and completed by freeze protecting the well with diesel. However, in this instance, prior to initiating disposal pumping, diesel was used to freeze protect one of the Oooguruk production wells. Upon completion of that operation, the valve from the diesel tank was inadvertently left open. This allowed stored diesel product to be drawn into the disposal well during the subsequent disposal operation instead of the waste slurry that Pioneer intended for disposal. The injection pump operator noticed the anomalous density and temperature readings and quickly ceased injection at approximately 4:17 a.m. Based upon operating records and two separate calculations of the volume of diesel injected, Pioneer estimates that 44 barrels of diesel were inadvertently injected.' There was, and there is, no endangerment to health, the environment, DW-1 or the injection zone. Injection of diesel used to freeze protect DW-1 into DW-1 is authorized in Part II, ' The amount of diesel injected must be estimated based available information. Pioneer has concluded that the best estimate is 44 barrels, and that the maximum amount of diesel that was injected is 53 barrels. paragraph C.7, of Class I UIC Permit No. AK 11009-A issued to Pioneer by the U.S. Environmental Protection Agency, Region 10 ("EPA"). Because Pioneer routinely uses diesel for freeze protection of DW-1 and then injects it into the well, the fluids inadvertently injected in this instance are identical to fluids that are properly injected into DW-I on a regular basis. Pioneer's operator took swift corrective action to stop the injection within minutes of it beginning to occur, and prompt notification to the AOGCC was provided pursuant to Rule 7 of DIO 31 the same day.2 Pioneer did not economically benefit from this occurrence; rather, it lost the use of diesel product purchased and regularly used during its operations. Finally, following investigation of this incident, Pioneer is taking corrective action to prevent a reoccurrence of this event. Specifically, Pioneer is updating three operating procedures to explicitly require closing and checking of valve positions. A review of the updated procedures and other fluid management guidelines will be conducted with employees involved in disposal well operations. Thank you for your time and attention to this matter. If the AOGCC has any questions or concerns, please do not hesitate to contact me at (907) 343-2102. Sincerely, J. Patrick Foley Manager of Land and External Affairs Pioneer Natural Resources Alaska, Inc. 2 Pioneer has also provided verbal notice to Thor Cutler of EPA, and will be providing a written explanation to EPA pursuant to paragraph E.13 of Class I UIC Permit No. AK I I009-A. 73495457.1 0053601-00002 11 • • RECEIVE PIONEER OCT 312012 NATURAL RESOURCES ALASKA AOGCC Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (9071 277-2700 Fax: (9071 343 -2190 October 26, 2012 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2011 -2012 Annual Performance Review for Oooguruk Unit DW 1 Dear Commissioner Foerster: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW -1), in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) Disposal Injection Order No 31, Rule 6. This surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by November 1 of each year and include data sufficient to characterize the disposal operation: • Pressures and injection rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW -1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, summarized, and included in this report for dates from October 1, 2011 through September 30, 2012. DW -1 Injection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from twice daily samplings during injection periods; additional raw data can be provided upon request. Attachment 7 is a graphical representation of the tabular data. Oooguruk Development Project • DW -1 2010 -2011 Annual Performance Report October 26, 2012 Page 2 DW -1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. Attachment 3 includes a summary of physical, chemical, and other relevant characteristics of injected fluids. Assessment of Fracture Geometry No additional assessment has been completed since the modeling done in June 2008 that supported a 6 bpm injection rate and 14 ppg. Description of Anomalous Injection Results Attachment 7 is a graphical plot of injection, inner annulus, and outer annulus pressures. Three anomalous data points were realized during this reporting period. The first anomaly occurred on January 28, 2012 which exceeds the 3500 psi pressure limitation on inner annulus. The pressure was exceeded during the annual mechanical integrity testing required by State and Federal agencies. The second and third anomalies occurred on February 15, 2012 during a caliber check on the inner and outer annuli pressure transducers. Calculated Zone of Influence for Injection Fluids No changes have been made since Pioneer submitted a model in June 2008 that supported the current injection rate of 6 bpm. The Zone of Influence is still considered to be similar to modeling conducted for this disposal operation. Other Attachment 5 is the test form from the EPA and AOGCC- witnessed mechanical integrity test that was conducted on the inner annulus January 16, 2011. Attachment 4 is a copy of the Notice of Inspection from the above test. Attachment 6 is the trend data of the test. If you have any questions or require additional information, please contact Tim Crumrine at (907) 343 -2184 or tim.crumrine@pxd.com. Sincerel Vern Johnson Drilling Manager - Alaska Oooguruk Development Pro • DW-1 2010-2011 Annual Performance Report October 26, 2012 Page 3 Enclosures: Attachment 1: DW -1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals Attachment 3: Waste Stream Summary Attachment 4: MIT -IA Notice of Inspection Attachment 5: MIT -IA Test Form Attachment 6: MIT -IA SCADA Plot Attachment 7: Pressure Plot of Injection Data II • Attachment 1 Average Average Maximum Maximum Injection Injection Average Injection Injection Minimum Rate Pressure Temperature Rate Pressure Injection Date (bbl /min)F (psi)WH ( °F) (bbl /min) (psi) Pressure (psi) 1- Oct -11 5.03 2,035 51 5.81 2,163 1,840 2- Oct -11 4.80 2,032 53 5.81 2,124 1,838 3- Oct -11 4,62 2,060 57 5.84 2,180 1,822 4- Oct -11 3.99 1,958 68 5.02 2,110 1,809 5- Oct -11 4.90 2,037 51 5.84 2,121 1,834 6- Oct -11 4.36 2,015 57 5.10 2,135 1,795 7- Oct -11 4.48 2,040 59 5.90 2,147 1,814? 8- Oct -11 4.75 2,049 59 5.85 2,146 1,830 9- Oct -11 4.92 2,033 56 5.52 2,121 1,805 10-Oct-11 4.53 2,018 55 5.82 2,129 1,777 11- Oct -11 4.25 2,032 57 5.86 2,175 1,819 12- Oct -11 4.23 1,955 64 5.83 2,210 1,669 13- Oct -11 4.28 1,874 68 5.82 2,190 1,611` 14- Oct -11 4.42 1,961 71 5.93 2,227 1,684 15- Oct -11 4.38 2,016 68 5.82 2,250 1,821 16- Oct -11 4.59 2,059 67 5.89 2,256 1,818 17- Oct -11 4.51 2,091 ` 62 5.80 2,255 1,575" 18- Oct -11 4.17 2,070 67 5.50 2,258 1,882 19- Oct -11 5.36 2,179 56 5.82 ` 2,276 1,910` 20-Oct-11 4.08 1,966 72 5.75 2,268 1,763 1 21- Oct -11 3.96 2,064 62 4.35 2,221 1,750' 22-Oct-11 4.11 2,072 63 5.76 2,236 1,813 23- Oct -11 3.98 2,023 64 4.36 2,248 1,615; 24- Oct -11 3.99 1,958 72 4.36 2,250 1,585 25- Oct -11 4.17 2,162 48 4.36 2,256 1,858' 26- Oct -11 3.91 2,078 64 4.34 2,267 1,898 27- Oct -11 3.88 2,090 60 4.34 2,276 1`,725' 28- Oct -11 4.04 2,082 58 4.34 2,264 1,753 29- Oct -11 4.13 2,181 48 4.34 2,283 1,931 30- Oct -11 4.00 2,055 64 4.36 2,943 1,803 31- Oct -11 3.95 2,072 57 4.35 2,277 1,653 1- Nov -11 3.72 2,078 54 4.35 2,263 1,616 2- Nov -11 3.98 1,843 66 4.36 2,487 1,300 3- Nov -11 3.92 1,999 67 4.42 2,267 1,296 4- Nov -11 3.63 2,173 61 4.34 2,456 1,924 5- Nov -11 4.91 2,211 48 5.81 2,507 1,907 6- Nov -11 4.56 2,220 52 5.80 2,306 1,937 7- Nov -11 4.30 2,105 63 5.80 2,293 1,822 8- Nov -11 4.78 2,197 57 5.80 2,292 1,998 9- Nov -11 4.63 2,203 53 5.81 2,426 1,894 10- Nov -11 4,86 2,212 51 5.79 2,342 1,934 11- Nov -11 4.66 2,235 55 5.78 2,342 2,058 12- Nov -11 4.35 2,178 54 5.78 2,326 1,987 • Attachment 1 • 13- Nov -11 4.05 2,229 49 4.29 2,315 1,976 14- Nov -11 4.45 2,175 58 5.91 2,359 1,974 15- Nov -11 4.84 2,231 53 5.78 2,371 1,936 16- Nov -11 4.77 2,211 54 5.82 2,400 1,772 17-Nov-11 4.99 2,252 52 5.83 2,376 1,988 18- Nov -11 4.95 2,248 52 5.81 2,368 2,025, 19- Nov -11 4.96 2,210 51 5.82 2,361 1,903 20- Nov -11 4.76 2,236 53 5.82 2,413 2,058 21- Nov -11 4.52 2,210 54 5.83 3,062 2,060 22- Nov -11 5.24 2,282 47 5.83 2,595 2,095 23- Nov -11 4.71 2,269 50 5.84 2,968 1,998 24- Nov -11 4.86 2,274 50 5.80 2,391 2,045 25- Nov -11 4.36 2,312 52 5.84 3,083 2,042 26- Nov -11 4.51 2,304 54 5.83 3,166 2,035 27- Nov -11 5.16 2,284 46 6.00 2,396 2,111 28- Nov -11 3.85 2,226 56 5.02 2,315 2,018 29-Nov-11 3.84 2,408 61 5.83 3,067 1,998 30 - Nov -11 4.38 2,238 53 5.86 2,600 ; 6 1- Dec -11 4.16 2,309 61 5.90 2,598 1,972 2- Dec -11 4.25 2,160 60 5.79 2,352 1,980 3- Dec -11 4.32 2,159 60 5.81 2,377 1,966 4- Dec -11 4.35 2,152 60 5.82 2,373 ; 1,933 5- Dec -11 4.37 2,165 59 5.85 2,402 1,852 6- Dec -11 4.56 2,148 62 5.81 2;384 1,900 7- Dec -11 4.53 2,202 58 5.81 2,384 1,932 8- Dec -11 4.80 ` 2,260 50 5.81 2,377 1,997 9- Dec -11 4.62 2,219 55 5.81 2,375 1,945 10- Dec -11 5.10 2,285 46 5.81 2,346 2,044 11- Dec -11 4.81 2,267 51 5.81 2,374 1,967 12- Dec -11 • 4.58 2,292 53 5.79 2,373 2,115 13- Dec -11! 4.71 2,285 54 5.78 2,360 2,091 14- Dec -11 4.56 2,254 59 5.90 2,400 1,922 15- Dec -11` 5.03 2,214 50 5.85 2,402 1,867 16- Dec -11 5.12 2,240 49 5.84 2,389 1,968 17- Dec -11 4.80 2,231 53 5.84 2,399 1,960 18- Dec -11 5.50 2,320 49 5.87 2,944 , 2,112 19- Dec -11 4.58 2,212 63 5.84 2,402 2,081 20- Dec -11 4.61 2,193 63 5.84 2,380 2,008 21- Dec -11 4.90 2,223 53 5.83 2,387 1,960 22- Dec -11 4.44 2,199 65 5.84 2,384 1,976 23- Dec -11 4.52 2,179 63 5.83 2,376 1,990 24- Dec -11 4.54 2,189 65 5.83 2,386 1,990 25- Dec -11 4.60 2,186 63 5.81 2,356 1,969 26- Dec -11 4.87 2,222 62 5.84 2,376 1,963 27- Dec -11 4.55 2,197 58 5.84 2,360 1,818 28- Dec -11 3.92 2,178 60 5.81 2,315 1,928 29- Dec -11 4.66 2,218 66 5.87 2,362 1,979 • Attachment 1 ID 30- Dec -11 4.87 2,241 57 5.82 2,345 1,930 31- Dec -11 4.29 2,138 68 5.82 2,448 1,731 1- Jan -12 4.58 2,196 59 5.93 2,393 1,852 2- Jan -12 4.93 2,250 55 5.80 2,373 1,957 3- Jan -12 4.83 2,253 61 5.81 2,375 1,878 4-Jan-12 4.69 2,230 61 5.80 2,377 1,957 5- Jan -12 1.72 1,419 64 2.07 1,906 ; 947 6- Jan -12 4.58 2,148 70 5.93 2,371 1,816 7-Jan-12 5.17 2,232 56 5.85' 2,349 1,947 8- Jan -12 4.83 2,232 59 5.83 2,402 1,919 9- Jan -12 5.18 2,231 56 5.83 2,338 1,923 10-Jan-12 4.59 2,233 56 5.84 2,647 1,827 11- Jan -12 5.13 2,232 59 5.82 2,375 1,886 12- Jan -12 4.90 2,205 57 5.83 2,361 1,842 13- Jan -12 5.34 2,257 55 5.89 2,387 1,893 14- Jan -12 4.45 2,119 56 5.83 2,314 1,725 15-Jan-12 4.85 2,061 60 5.84 2,372 1,731 16- Jan -12 4.37 2,068 67 5.82 2,406 1,843 17- Jan -12 4.51 2,123 69 5.84 2,438 1,869! 18- Jan -12 4.42 2,172 76 5.83 2,650_ 1,841 19- Jan -12 3.90 ` 2,198 67 5.00 2,362 1,929 20- Jan -12 3.28 2,172 62 4.34 2,338 1,874 21- Jan -12 2.71 2,133 68 4.05 2,351 1,890 22- Jan -12 3.06 2,259 56 4.03 2,392 2,036 I 23- Jan -12 2.51 2,149 57 4.03 2,360 1,951£ 24-Jan-12 3.25 2,203 56 4.05 2,358 1,944 25- Jan -12 3.82 2,270 47 4.05 2,358 1,965 26- Jan -12 3.54 2,199 52 4.07 2,338 1,945 27-Jan-12 3.63 2,236 51 4.01 2,506 1,970 28- Jan -12 3.45 2,169 59 5.79 2,562 2,031 29-Jan-12 3.86 2,152 58 5.82 2,374 1,935 30-Jan-12 4.13 2,103 63 5.81 2,379 1,815 31- Jan -12 4.87 2,232 52 5.83 2,382 1,892 1- Feb -12 5.18 2,290 55 5.89 2,384 1,901 2- Feb -12 3.89 2,215 53 5.83 2,402 2,001 3- Feb -12 4.10 2,249 61 5.82 2,363 2,087 4- Feb -12 4.70 2,298 55 5.82 2,417 1,864 5- Feb -12 4.58 2,236 61 5.82 2,416 1,954 6- Feb -12 4.00 2,090 66 5.80 2,356 1,585 7- Feb -12 4.68 2,183 61 5.90 2,434 1,531 8- Feb -12 4.80 2,131 58 5.83 2,384 1,763 9- Feb -12 4.25 2,256 49 5.80 2,418 1,880 10- Feb -12 4.42 2,212 61 5.79 2,475 1,836, 11- Feb -12 4.92 2,168 53 5.85 2,427 1,505 12- Feb -12 4.60 2,121 62 5.81 2,444 1,572 13- Feb -12 4.04 2,134 70 5.81 2,635 1,470 14- Feb -12 4.25 2,174 58 5.81 2,430 1,696 • Attachment 1 • 15-Feb-12 5.17 2,303 50 5.79 2,381 2,013 16- Feb -12 4.29 2,245 59 5.87 2,759 1,844 17-Feb-12 4.76 2,119 56 5.82 2,433 1,662 18- Feb -12 4.49 2,142 59 5.81 2,408 1,714 19- Feb -12 5.14 2,274 49 5.80 2,392 1,785 20- Feb -12 4.41 2,090 61 5.83 2,499 1,625 21- Feb -12 4.01 2,218 52 4.35 2,372 1,882 22- Feb -12 3.85 1,973 67 4.37 2,375 1,370 23- Feb -12 3.99 2,149 74 4.33 2,370 1,836 24- Feb -12 4.07 2,294 67 4.36 2 2 25-Feb-12 4.15 2,287 54 4.35 2,373 2,018 26- Feb -12 4.00 2,336 59 4.31 2,405 2,027 27- Feb -12 3.93 2,241 64 4.31 2,532 1,900 28- Feb -12 4.01 2,290 56 4.34 2,438 2,015 29- Feb -12 3.81 2,287 59 4.31 2,395 1,936 1- Mar -12 3.71 2,346 60 4.30 2,826 2,050 2- Mar -12 3.59 2,379 61 4.29 2,853 1,961 3- Mar -12 3.60 2,381 73 4.29 2,458 2,115 4- Mar -12 3.81 2,409 62 4.33 2,756 2,103 5- Mar -12 3.87 2,395 54 4.29 2,847 ` 2,133: 6- Mar -12 3.67 2,348 69 4.28 2,481 2,052 7- Mar -12 3.71 2,356 75 4.38 2,432 2,10E 8-Mar-12 3.87 2,349 61 4.05 2,417 2,132 9- Mar -12 3.76 2,325 57 4.00 2,404 2,078 10- Mar -12 3.71 2,306 64 4.06 2,428 2,046 11- Mar -12 3.78 2,310 64 4.01 2,408 ` 2,145 12- Mar -12 3.81 2,298 63 4.04 2,405 1,843 13- Mar -12 3.75 2,289 67 4.03 2,421 2,086 14- Mar -12 3.84 2,305 70 4.31 2,433 2,044 15- Mar -12 3.77 2,370 76 4.01 µ; 2,419 2,161 16- Mar -12 3.82 2,357 55 4.24 2,427 2,134 17- Mar -12 3.72 2,366 60 3.99 2,428 2,071 18- Mar -12 3.77 2,341 57 4.02 2,414 2,181 19- Mar -12 3.81 2,354 62 4.01 2,430 2,088 20- Mar -12 3.80 2,352 61 4.08 2,409 2,059 21- Mar -12 3.82 2,298 63 4.30 2,418 2,135 22- Mar -12 3.81 2,414 66 4.10 2,588 2,193 23- Mar -12 3.93 2,406 66 4.29 2,477 2,281:, 24- Mar -12 3.84 2,326 68 4.30 2,443 1,895 25- Mar -12 4.16 2,378 52 4.29 2,399 2,192 3.75 2,355 60 4.03 2,409 2,012 27- Mar -12 3.96 2,335' 57 4.29 2,416 1,998 28- Mar -12 3.93 2,325 66 4.35 2,448 2,039 29- Mar -12 4.08 2,234 65 5.03 2,459 1,901' 30- Mar -12 3.90 2,263 62 4.32 2,447 1,732 31- Mar -12 4.02 2,219 66 5.79 2,499 1,884 1- Apr -12 4.15 2,283 72 5.83 2,507 2,090 • Attachment 1 2- Apr -12 4.99 2,353 57 5.83 2,506 2,105 3- Apr -12 4.56 2,207 69 5.85 2,411 1,904 4- Apr -12 4.36 2,269 59 5.02 2,372 1,954 5-Apr-12 4.34 2,225 64 5.78 2,403 2,067 6- Apr -12 4.27 2,232 65 5.77 2,370 2,002 7-Apr-12 4.29 2,231 79 5.83 2,660 1,922 8- Apr -12 4.82 2,330 84 5.86 2,765 1,948 9-Apr-12 4.31 2,284 86 5.86 2,762 1,783 10- Apr -12 4.87 2,394 89 5.88 2,671 1,939 11- Apr -12 4.79 2,279 82 5.82 2,672 1,901 12- Apr -12 4.50 2,226 81 5.91 2,640 1,882, 13- Apr -121 5.07 2,247 75 5.85 2,437 1,976 14- Apr -12 4.74 2,099 69 5.82 2,324 1,588 15- Apr -12 4.69 2,160 56 5.84 2,575 1,498 16-Apr-12 ',''''5:.'",*if 3.95 2,263 57 5.81 2,720 1,712 17- Apr -12? 4.56 2,369 59 5.82 2,623 2,042 18- Apr -12 4.20 2,404 72 5.86 2,669 2,018 19- Apr -12 4.68 2,328 67 5.83 2,660 2,021 20- Apr -12 4.90 2,275 63 5.91 2,411 1,993 21- Apr -12 4.89 2,244 64 5.80 2,380 1,816 22- Apr -12 5.10 2,227 61 5.83 2,350 2,043 23- Apr -12 4.28 2,342 62 5.83 2,642 1,991 24- Apr -12 4.12 2,454 66 5.84 2,617 2,015 25-Apr-12 4.59 2,205 67 5.82 2,366 2,053 26- Apr -12 4.70 2,179 66 5.80 2,352 1,926 5.29 2,234 60 5.80 2,308 2,017 28- Apr -12 4.94 2,185 63 5.82 2,346 1,865 29- Apr -12 4.37 2,199 62 5.84 2,533 1,850 30- Apr -12 5.05 2,243 62 5.82 2,367 1,906 1- May -12 4.97 2,220 63 5.85 2,415 1,908 2- May -12 4.31 2,131 71 5.83 2,413 1,826 3- May -12 4.38 2,208 70 5.83 2,415 1,976 4- May -12 4.48 2,186 73 5.85 2,415 1,887 5- May -12 4.30 2,217 66 5.82 2,433 1,841 6- May -12 4.82 2,255 62 5.81 2,412 1,860 7- May -12 4.68 2,242 69 5.89 2,399 1,988 8- May -12 4.50 2,298 67 5.81 2,600 1,968 9- May -12 5.30 2,281 59 5.85 2,362 1,953 10- May -12 4.53 2,221 67 5.82 2,357 1,925 11- May -12 4.59 2,217 59 5.84 2,348 1,834 12- May -12 5.23 2,241 59 5.90 2,358 1,905 13- May -12 5.40 2,250 57 5.84 2,355 2,032 14- May -12 4.44 2,247 67 5.85 2,366 1,895 15-May-12 4.56 2,245 62 5.84 2,506 1,912 16- May -12 4.68 2,252 58 5.84 2,374 2,107 17- May -12 5.00 2,299 54 5.83 2,387 2,081 18- May -12 0.00 0 0 0.00 0 0 • Attachment 1 • 19- May -12 4.11 2,245 61 5.85 2,581 1,910 20- May -12 4.80 2,141 63 5 2,365 1,859 21- May -12 5.07 2,238 54 5.89 2,386 1,872 22- May -12 4.93 2,215 59 ` 5.86 2,386 1,792 23- May -12 4.06 2,111 63 5.82 2,741 1,746 24- May -12 3.73 2,091 ' 58 4.05 2,313 1,598 25- May -12 3.82 2,232 51 3.98 2,643 1,885 26- May -12 3.69 2,042 62 4.04 2,359 1,274 27-May-12 3.82 2,239 50 4.04 2,352 1,819 28- May -12 3.72 2,220 51 3.98 2,359 1,778 29-May-12 3.77 2,176 58 4.02 2,352 1,845 30- May -12 3.82 2,201 56 4.05 2,374 1,917 31- May -12 3.90 2,233 51 4.02 2,376 1,928 1-Jun-12 3.68 2,210 56 4.05 2,373 1,896' 2-Jun-12 3.82 2,236 56 4.06 2,369 1,975 3- Jun -12 3.65 2,222 57 4.04 2,399 1,990; 4- Jun -12 3.63 2,256 57 4.06 2,389 1,989 5-Jun-12 3.76 2,196 59 4.03 2,403' 1,839 6- Jun -12 3.71 2,214 57 4.04 2,393 1,896 7- Jun -12 3.85 2;247 58 4.28 2,469; 1,896 8-Jun-12 3.80 2,303 56 4.05 2,429 2,136 9- Jun -12 3.82 2,258 60 4.28 2,699 1,792, 10- Jun -12 3.81 2,230 60 4.27 2,480 1,791 11- Jun -12 3.85 2,301 54 4.28 2,423 2,023 12- Jun -12 3.75 2,338 54 4.06 2,437 2,064 13- Jun -12 3.82 2,302 55 4.27 2,427' 2,044' 14-Jun-12 3.75 2,301 56 4.03 2,410 2,036 15- Jun -12 3.88 ' 2,301 54 4.27 2,409 2,038 16- Jun -12 3.89 2,259 55 4.27 2,410 2,087 17- Jun -12 178 2,288 56 4.05 2,402 2,002 18- Jun -12' 3.75 2,303 56 4.26 2,406 2,096 19- Jun -12 3.87 2,284 54 4.03 2,706 2,074 20- Jun -12 3.78 2,205 68 4.06 2,423 1,857 21- Jun -12 3..79 2,210 65 4.03 2,441 1,832 22- Jun -12 3.81 2,201 64 4.06 2,460 1,927 23- Jun -12 3.71 2,258' 68 4.06 2,484 2,007! 24- Jun -12 3.82 2,325 63 4.04 2,514 2,109 25- Jun -12 3.80 2,353 53 4.00 2,512 2,132: 26- Jun -12 3.78 2,347 59 4.47 2,547 2,053 27- Jun -12 3.73 2,417 54 4.31 2,532 2 28- Jun -12 3.79 2,421 53 4.06 2,663 2,186 29- Jun -12 3.78 2,391 61 4.03 2,509 2,207 30- Jun -12 3.74 2,345 60 4.04 2,449 2,111 1- Jul -12 3.87 2,028 63 4.05 2,661 1,618 2- Jul -12 3.74 2,017 57 4.04 2,182 1,705 3- Jul -12 3.76 2,000 64 4:10 2,154 1,682 4- Jul -12 3.80 1,954 54 4.28 2,166 1,639 i Attachment 1 • 5- Jul -12 3.81 1,927 55 4.11 2,063 1,518 6- Jul -12 3.86 1,998 54 4.15 2,189 1,698 7- Jul -12 3,84 1,993 58 4.12 2,178 1,742 8-Jul-12 4.86 2,072 52 5.85 2,312 1,679 9- Jul -12 4.52 2,023 57 5.83 2,290 1,744 10- Jul -12 4.60 2,137 65 5.85 2,332 1,740 11- Jul -12 4.81 2,145 59 5.84 2,312 1,809" 12-Jul-12 4.59 2,133 57 5.83 2,281 1,880 13- Jul -12 4.64 2,125 61 5.85 2,307 1,828 14- Jul -12 4.70 1,998 60 5.85 2,293 1,669 15- Jul -12 4.72 1,912 65 5.90 2,297 1,473 16-Jul-12 4.63 1,959 64 5.85 2,301 1,468 17- Jul -12 5.08 2,073 52 5.84 2,282 1,516 18- Jul -12 4.80 1,924 60 5.83 2,242 1,404 19- Jul -12 4.80 1,944 56 5.84 2,203 ` 1,403 20- Jul -12 4.55 1,758 69 5.84 2,284 1,303 21- Jul -12 4.45 1,674 71 5.86 2,258 1,167 22- Jul -12 4.69 1,869 60 5.84 2,152 1,551 23- Jul -12 4.60 1,983 59 5.85 2,170 1,740 24- Jul -12 3.04 1,891 52 5.81 2,122 1,694 25- Jul -12 3.76 1,976 70 4.05 2,318 1,695' 26- Jul -12 4.80 2,037 53 5.84 2,229 1,717 27- Jul -12 4.66 2,012 61 5.83 2,161 1,758 28- Jul -12 4.49 1,838 73 5.81 2,262 1,454 29- Jul -12 4.41 1,957 57 5.82' 2,158 1,573'' 30- Jul -12 4.71 1,878 69 5.83 2,164 1,573 31- Jul -12 4.64 ; 1,943 63 5.82 2,167 1,584 1- Aug -12 4.88 1,922 67 5.86 2,183 1,601 2- Aug -12 5.42 1,998 64 5.81 2,184 1,738 3-Aug-12 4.70 1,976 67 5.82 2,240 1,674 4- Aug -12 5.40 2,083 56 5.80 2,202 1,759 5- Aug -12 0.00 0 0 0.00 0 0 6- Aug -12 4.65 2,046 74 5.79 2,265' 1,719 7-Aug-12 4.73 2,049 63 5.80 2,215 1,735 8- Aug -12 4.74 2,037 64 5.80 2,222 1,692 9- Aug -12 0.00 0 0 0.00 0 0 10- Aug -12 0.00 0 0 0.00 0 0 11-Aug-12 5.46 1,983 53 5.84 2,141 1,722 12- Aug -12 5.53 1,978 58 5.92 2,336 1,715' 13-Aug-12 5.46 1,954 63 5.82 2,204 1,707 14- Aug -12 4.79 1,964 60 5.84 2,270 1,680 15- Aug -12 4.55 1,916 65 5.80 2,259 1,744 16- Aug -12 4.30 1,895 67 5.81 ' 2,281 1,572' 17- Aug -12 4.37 1,909 65 5.79 2,219 1,508 18- Aug -12 4.26' 1 ,890 70 5.79 2,251 1,518° 19- Aug -12 3.94 2,155 67 4.99 2,525 1,499 20- Aug -12 4.17 2,204 64 5.83 2,511 1,794 • Attachment 1 • , 21- Aug -12 4.44 2,104 67 5.88 2,483 1,751 22- Aug -12 4.69 2,201 65 5.88 2,286 1,872 23-Aug-12 4.33 2,129 64 5.84 2,312 1,763 24- Aug -12 4.37 2,121 68 5.80 2,275 1,818 25- Aug -12 3.93 2,029 76 5.78 2,283 1,783 26- Aug -12 4.61 '; 2,044 66 5.83 2,304 1,729 27- Aug -12 4.36 2,060 68 5.82 2,310 1,758 28- Aug -12 4.50 2,039 73 5.81 2,284 1,777 29- Aug -12 4.62 2,098 66 5.83 2,306 1,799 30- Aug -12 4.95 2,041 66 5.83 2,301 1,805 31- Aug -12 4.57 2,077 63 5.84 2,307 1,707 1- Sep -12 4.71 2,104 65 5.88 2,296 1,799 2- Sep -12 4.89 2,091 62 5.85 2,274 1,800 3- Sep -12 4.82 2,069 62 5.85 2,292 1,758 4- Sep -12 4.62 2,071 68 5.84 2,276 1,788 5- Sep -12 4.68 2,116 64 5.84 2,247 1,790 6- Sep -12 4.64 2,113 67 5.83 2,261 1,794 7- Sep -12 � - ; 4.54 2,104 63 , 5.84 2,252 1,770 8- Sep -12 4.60 2,112 65 5.83 2,226 1,804 9- Sep -12 4.71 2,132 64 5.85 2,316 1,782 10- Sep -12 4.79 2,113 62 5.83 2,290 1,812 11- Sep -12 4.97 ' 2,076 59 5.84 2,278 1,742 12- Sep -12 4.66 2,038 56 5.80 2,200 1,608 13- Sep -12 4.57 2,028 63 5.82 2,316 1,583 14- Sep -12 4.84 2,114 61 5.80 2,283 1,780 15- Sep -12 5.11 2,086 58 5.81 2,282 > 1,737 16-Sep-12 5.41 2,114 54 5.80 2,243 1,807 17- Sep -12 5.26 2,100 63 5.79 2,191 1,790: 18- Sep -12 4.52 2,032 59 5.80 2,244 1,745 19- Sep -12 5.15 2,062 58 5.80 2,167 1,722! 20- Sep -12 4.38 2,081 65 5.82 2,263 1,711 21- Sep -12 4.57 2,067 68 5.82 2,235 ` 1,742 22- Sep -12 4.17 2,077 87 5.81 2,273 1,746 23- Sep -12 4.14 2,047 80 5.81 2,297 1,742 24-Sep-12 4.25 1,987 83 5.82 2,281 1,667 25- Sep -12 4.15 2,056 83 5.80 2,558 1,777 26- Sep -12 4.63 2,013 66 5.82 2,275 1,631 27- Sep -12 5.02 2,061 57 5.81 2,252 1,697 28-Sep-12 4.44 1,956 72 5.82 2,251 1,714 29- Sep -12 4.99 2,002 60 5.85 2,236 1,693 30- Sep -12 4.93 2,004 61 5.84 2,200 1,685 Attachment 2 :onthly Inflection Totals and Waste Stream Summary Monthly Injection Totals Volume of Month Injected Fluid (BBLS) October 2011 53801 November 2011 49572 December 2011 63706 January 2012 55783 February 2012 52803 March 2012 59421 April 2012 71744 May 2012 45903 June 2012 50149 July 2012 45421 August 2012 51173 September 2012 50226 Page 1 of 1 • Attachment 3 - Waste Streams Summary Physical, Chemical, and Other Relevant Characteristics of the Injected Fluids Non- Exempt Typical Sampling Conducted or Primary Constituents Waste SAIIIIIIIMMINIIMEM110111MININIEL. Generator /Process Knowledge • Incidental non - hazardous wastes Wash water, seawater used generated by module operations & for drilling mud make -up, Waste characterization sampling Utility modules sump maintenance completed and verified not RCRA- potable water chemical fluids • Incidental equipment leaks hazardous — Generator knowledge • Additives for Reverse Osmosis & potable additives. Process control is used water systems p strictly maintained • Vehicles & equipment (antifreeze) Waste characterization sampling Glycol /heat exchange Glycol (MEG, DEG, TEG, completed and verified not RCRA- media • Module and facility heating and cooling propylene) hazardous — Confirmation sample systems 08 -01 -12 • Fluids recovered from cleanup of non- Water, snow, gravel, with Waste characterization sampling Non - exempt spill completed and verified not RCRA- exempt spills hydrocarbon or chemical clean -up • Spill impacted gravel or snow products hazardous — Generator knowledge used Water, glycol, possible Waste characterization sampling Hydrotest fluid • Pressure test new or non - exempt process product residual in existing completed and verified not RCRA- (water or glycol only) lines, vessels lines, traces of chlorine or hazardous — Generator knowledge other biocide used Boiler blowdown • Rig or production facility boilers Water Not injected year to date, fluids used for drilling mud make -up water Off spec product • Products spilled, out -dated or no longer Varies — MSDSs reviewed Not injected year to date acceptable for original purpose • Outdoor containment around fuel and Water, possible traces of Waste characterization sampling Contained snow/ chemical storage tanks hydrocarbon or chemicals if completed and verified not RCRA- ponded water • Depressions on or between pads & roads there have been spills hazardous — Generator knowledge used • Motor oil Routine verification sampling Lubrication oil • Transmission fluid Hydrocarbons /water mixes conducted to confirm not RCRA- • Hydraulic oils hazardous — Typically sent to hydrocarbon or offsite recycle • Internal or external washdown of skids, modules Water, possible traces of Waste characterization sampling Non - exempt facility • Equipment cleaning (using non- hydrocarbon, chemicals, completed 09 -14 -12 and verified not wash water hazardous detergents or degreasers) detergent RCRA- hazardous • Residues removed from RCRA -empty containers • Trash and camp waste Waste characterization sampling Incinerator ash .Sewage sludge Particulates /RCRA metals completed 07 -19 -12 and verified not RCRA- hazardous Domestic • Camp wastewater treatment plant(s) and Water, soap residuals, human NPDES permitted facility, RCRA wastewater/ sludge site enviro -vacs waste Exempt • Saline concentrate from reverse osmosis Waste characterization sampling Reverse osmosis process for making potable water from Saline water completed and verified not RCRA- concentrate /seawater seawater hazardous — Generator knowledge used Notes: 1. Similar wastes may be RCRA exempt, depending on waste - generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 • • • Attachment 4 NOTICE OF INSPECTION ir'' <• • > U.S Environmental Protection Agency Offiee of Compliance and Enft a ment (OC'F? ) '7 ` C, Water Protection Unit (MC) Program Phone (?r)b) 553.i67 41 ri ; ; g$ 1200 Sixth Avenue Suite 900 (OCE- 27) Seattle, WA 98 t +l l (." L t r <4'y nn a) F ` t Finn Name &a Address: II1C al A r. 1 :... Coc , A C i ^� �t UU r I r t. }'IAe lT r t4 of t'',Al • — � .1-. =y- e. . or) ,,:,, .e. „ .., ... :5, ^1 Y 8 4) !,. ! t U -' L...: t. t ^ htaprctor llama & Signature —� ., W e Thor Cutler 2,F4.( - 'L f ''t._. Dare / a la' fa -- •� l L� If O • x t2■ C. s ftt _ / " /L•! /CIPI' 14040— ice / e / iNSPEC'T1ON TYPE: C oniidiance (Routine' . 1"-as TestingSampling t:loaere„ , •a.. , NOTICE OF INSPECTION IS HEREBY ( ;IVFN ACCORDING TO SF :( :TIC» 1445 (13) OF nit SAFE DRINKING %%A TER ACT (42 U.S.C. 300 F et seq.) REASON FOR ENSPECTION: For the purpose of inspecting rteamla, tiles, papery, processes, controls and facilities, artd nr obtaining samples to determine whether cite person subjee:t to an applicable underground injection control program has acted or is acting, in compliance with the Safe Drnnk:na Water At and any applicable permit or rule. Text of t42 LS,S. 300-j-4 (b) Section 1445 for of the Safe Drinking Witter Act tbg l t Except ae provided in (x ragraph (2), the Awtiinintratur, or representatives of the Administrator duly assigned by hint, upon presenting appropriate credentials and a written notice to any supplier of water or other person s °t btcct to (A) a national primary drinking water regulation prescribed under section 1412 (t)) an applicable underground i:t„ection control program or (C) any requirement to monitor an unregulated contaminant pursuant to subsection tat. or person in charge of any of the property of such supplier or of er person, ia authorized to enter any establishment, facility. or other property of such supplier or other person in order to determine whether such supplier or other person has acted or is acting an compliance with this title, including. for this purpose, irspes:tion, at reasonable times, of records, files. papers, processes. controls, and facilities, or in order to test any feature of a public water system, inalueling its raw water source. The Administrator or the Controller General (or any representative dcsignsecd. by either) shall have access for the purpose of audit and examination to any records, reports, or infonration of a grantee which are required to he maintained under subsection t•i) or which are pertinent to nosy financial assistance under this title. 1.21 No entry may he made under the first sentence of paragraph ( i) in an establishment, facility, or ; property of water or other person subject to a national primary drinking water regulation if the establishment, facility, or other property is located in a State which has primacy Llifnrcnncrn responsibility for public water systems unless. before written notice of such cony is made, the Administrator for his rcr,resa:tati ve) notifies the State agency charged with responsibility for safe drinking water of the reasons for such entry. The Administrator shall. upon a showing by the State agency that such entry will be detrimental to the administration of the Stares program of primary enforcement responsibility, take such showing into co:tsitte `:son at determining whether to make such entry. No State agency which receives notice under this paragraph of an entry proposed to he made under paragraph (I) may use the information contained in the notice to inform the person whose: property is proposed to be entered of the proposed entry -, end if a State agency so t:aos such information. notice to the agency urcler this paragraph is not required until such time as the Administrator determines the agcyey has provided him sar'tstytctcry assurances that it will no longer so use infirm nation corrtaired in a notice under this paragraph 0 Whoever fails or refuse:; to comply with any requtreracn:t of sabsectiun t it Or to allow the Administrator, the Compnolle: General. or representatives of either. to trier :rod conduct any audit or inspection authorized by subsection (b) shall be subject to a civil penalty, not to exceed S 37,5100, ABC. • • Attachment 5 United States Environmental Protection Agency � ,,�� '' t Region 10 4 `` . 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e-mail: cutler.thor@epa.gov epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well I Permit No. PTD No. Pioneer - Oooguruk Unit ODSDW 01 -44 AK- 11009 -A 207 -140 Injector MIT Type I Test Type Test Date Class I _ T X IA Std. Annular Pressure Test (SAPT) + 1 /28/r a Req'd Test Fluid Types) used to Packer Depth (ft. Test Interval /Comments Pressure (psi) test TVD) 3,500 Diesel _ 5,035' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel/50:50 methanol/glycol pumped in annulus during test. T START TIME: RECORDED PRESSURES (PSI) RESULT E a�l t PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN i F S TUBING ff1 ►A111[/t T INNER ANNULUS 1 0!"ii] ]EM" OUTER ANNULUS Qm r �r/g/pm 1 COMMENTS: G�i � -c7UV g y 11/.t} to P.m.,- z/ d(bl T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS! T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL IS MIN 30 MIN 45 MIN 60 MIN S TUBING PASS! T INNER ANNULUS FAIL OUTER ANNULUS _ 3 COMMENTS: MISC COMMENTS: NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if I) Total loss exceeds 10 % 2) Loss during last 15 minute period = or 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 0 ( I — E -mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler ,¢�y l I 5e kovieri Jv.c 1)p ( mow tc u 1,0:1 4V50 0/1 GVK IT Attachment 6 Standard Annuluar Pressure Test Trend 0, Fa . Rs. . I lcustom _di 1/28/2012 7:03:04 PM J to f 1/28/2012 9:16:04 PM j Appi (1(2812012 8;030 PM) 3517 psi • (1/28/2012 8:38:19 PM) 3511 psi - 6 psi (0 days. 00:3-# :56; 10.000 6000.000 4000 6000.000 100 H 0 2094.000 0 • 0 a.000 7:04:23 PM 7:30:59 PM 7:57:35 PM 8:24:11 PM ! 8:50:47 PM 9:17:23 PM 1/28/2012 1/28/2012 1/28 /2012 1/28/2012 1/28/2012 1/28/2012 192.168.124.52:PI 41001 [Delta] ODSDW1 -44 Pressures Attachment7 Oct 1, 2011 through Sep 30, 2012 5 4F00 WHP OA °000 I A von 3 7500 'non ' f ,5nn • moo 50D _ ¢ N QQ N N N Q N e SQ N c N � E C C C C C-2" �" C 7 0 C a C 10 • • PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 October 31, 2011 Commissioner John Norman RECEIVED Alaska Oil and Gas Conservation Commission NOV 0 2 2.01E 333 West 7th Avenue, Suite 100 Al Anchorage, AK 99501 ska 011 & Gas Cons. Commission Ancttnr Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2010 -2011 Annual Performance Review for Oooguruk Unit DW 1 Dear Commissioner Norman: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW -1), in accordance with Alaska Oil and Gas Conservation Commission ( AOGCC) Disposal Injection Order No 31, Rule 6. This surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by November 1 of each year and include data sufficient to characterize the disposal operation: • Pressures and injection rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW -1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, summarized, and included in this report for dates from October 1, 2010 through September 30, 2011. DW - 1 Injection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from twice daily samplings during injection periods; additional raw data can be provided upon request. Attachment 7 is a graphical representation of the tabular data. • i Oooguruk Development Project DW-1 2010-2011 Annual Performance Report October 31, 2011 Page 2 DW -1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. Attachment 3 includes a summary of physical, chemical, and other relevant characteristics of injected fluids. Assessment of Fracture Geometry No additional assessment has been completed since the modeling done in June 2008 that supported a 6 bpm injection rate and 14 ppg. Description of Anomalous Injection Results Attachment 7 is a graphical plot of injection, inner annulus, and outer annulus pressures. Three anomalous data points were realized during this reporting period. On May 29 and 30, 2011, pressures of 3,878 psi and 4,322 psi respectively were recorded. Upon further investigation of pump operator data, the pressures were not related to the pumping of disposal waste. Please note that the pumps used with this well are used on other operations when not needed for injection into the disposal well. On July 10, 2011 an inner annulus pressure of 4,336 psi was recorded by Pioneer's SCADA system. A review of operator data shows an IA pressure of 62 psi. Calculated Zone of Influence for Injection Fluids No changes have been made since Pioneer submitted a model in June 2008 that supported the current injection rate of 6 bpm. The Zone of Influence is still considered to be similar to modeling conducted for this disposal operation. Other Attachment 4 is the test form from the EPA and AOGCC - witnessed mechanical integrity test that was conducted on the inner annulus January 16, 2011. Attachment 5 is a copy of the circle chart from the above test. Attachment 6 is the trend data of the test. If you have any questions or require additional information, please contact Tim Crumrine at (907) 343 -2184 or tim.crumrine©pxd.com. Sincer , /a/3(77/ Vern Johnson Drilling Manager - Alaska • • Oooguruk Development Project DW-1 2010-2011 Annual Performance Report October 31, 2011 Page 3 Enclosures: Attachment 1: DW -1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals Attachment 3: Waste Stream Summary Attachment 4: MIT -IA Test Form Attachment 5: MIT -IA Test Chart Attachment 6: MIT -IA SCADA Plot Attachment 7: Pressure Plot of Injection Data • i Attachment 1 Average Average Maximum Maximum Injection Injection Average Injection Injection Minimum Rate Pressure Temperature Rate Pressure Injection Date (bbl /min)F (psi)WH ( °F) _ (bbl /min) (psi) Pressure (psi) 1- Oct -10 4.10 2,136 51 5.80 2,245 1,916 2- Oct -10 4.69 2,147 56 5.81 2,273 1,800 3- Oct -10 4.42 2,153 47 5.86 2,241 1,604 4- Oct -10 4.15 1,982 63 5.80 2,275 1,771 5- Oct -10 3.90 2,070 56 5.81 2,237 1,671, 6 -Oct-10 4.48 2,075 59 5.81 2,274 1,705 7- Oct -10 3.70 1,800 59 5.80 _ 2,285 74 _ 8-Oct-10 2.12 1,358 77 5.80 2,471 263 9- Oct -10 4.19 2,168 44 5.81 2,249 2,037 10- Oct -10 3.84 2,101 50 5.80 2,256 1,792 11-Oct-10 5.07 2,207 52 5.79 2,284 2,075 _ 12-Oct -10 4.36 2,042 61 5.79 2,257 1,760 13- Oct -10 4.18 2,041 61 5.80 2,327 1,706, 14- Oct -10 4.56 2,154 50 5.79 2,345 1,778 15- Oct -10 4.25 2,176 50 5.78 2,364 1,718 - 16dkt -10 3.83 2,284 49 4.31 2,297 786 17- Oct -10 3.97 2,247 51 4.36 2,367 2,034 18- Oct -10 3.82 2,126 48 4.36 2,306 212 19- Oct -10 _ 4.18 2,176 68 5.8_0 2,398 2,053 20- Oct -10 4.20 2,199 55 5.81 2,338 1,961 21-Oct-10 4.85 2,237 48 5.80 2,327 2,099 22- Oct -10 4.46 2,212 50 5.80 2,333 1,954 23-Oct-10 3.64 2,085 46 4.36 2,248 27 24- Oct -10 4.06 2,186 50 4.37 2,286 35 25-Oct-10 3.77 2,169 59 4.36 2,307 1,983 26 -Oct-10 3.99 2,102 59 4.35 2,311 1,805 ` 27- Oct -10 3.89 2,111 66 4.34 2,327 1,882 28- Oct -10 3.10 1,444 78 4.36 2,326 232 29- Oct -10 2.58 916 91 4.36 2,964 209 30- Oct -10 3.45 2,226 58 4.32 2,454 2,026 31- Oct -10 3.48 2,299 55 5.79 2,571 6 1- Nov -10 3.87 2,423 64 5.87 2,720 1,820 2- Nov -10 3.68_ 2,305 71 4.39 2,727 1,859 3- Nov -10 3.75 2,127 87 4.38 2,436 1,283 4- Nov -10 3.61 2,301 78 5.87 2,700 1,928 5- Nov -10 4.18 2,336 57 5.82 2,506 2,174 6- Nov -10 4.02 2,239 58 _ 5.86 2,401 10 7- Nov -10 4.79 2,240 55 5.98 2,481 1,852 8- Nov -10 5.16 2,278 51 5.90 2,404 2,065 9- Nov -10 5.05 2,286 51 5.87 2,376 33 10- Nov -10 4.69 2,234 46 5.83 2,369 821 11- Nov -10 4.86 2,274 53 5.86 2,397 1,993 12- Nov -10 5.21 2,278 48_ 5.90 2,413 1,926 • • 13- Nov -10 4.65 2,214 51 5.97 2,373 1,962 14-Nov -10 3.97 2,225 52 4.38 2,366 1,993 15- Nov-10 4.06 2,252 48 4.37 2,377 2,038 _ 16- Nov -10 4.05 2,151 63 4.41 2,382 1,888 17- Nov -10 3.92 2,126 60 4.39 2,390 15 18- Nov -10 3.90 2,229 68 4.39 2,678 1,614 19- Nov -10 3.87 2,137 62 4.41 2,405 1,641 20- Nov -10 3.87 2,122 87 4.37 2,571 1,816 21- Nov -10 3.93 2,242 58 4.37 2,419 649 22- Nov -10 3.64 2,109 56 4.36 2,482 11 23- Nov -10 3.96 2,212 67 4.40 2,412 1,883 24- Nov -10 3.78 2,027 64 4.42 2,430 1,425 25- Nov -10 4.15 2,299 47 4.36 2,394 1,690 26- Nov -10: 4.16 2,281 48 4.37 2,382 2,046 27- Nov -10 4.04 2,238 49 4.37 2,370 1,795 28- Nov -10 4.55 2,252 49 5.88 2,392 1,900 29- Nov -10 4.48 2,231 56 5.88 2,396 1,858 30- Nov -10 0.94 1,606 52 1.97 1,929 ` 21 1- Dec -10 3.80 2,237 62 4.39 2,315 1,926 2- Dec -10 4.00 2,193 49 4.40 2,352 1,697, 3- Dec -10 3.99 2,214 48 4.38 2,374 1,951 4- Dec -10 4.07 2,248 49 4.38 2,384 2,091 5- Dec -10 3.92 2,248 55 4.37 2,372 2,019 6- Dec -10 3.88 2,207 68 4.37 2,387 1,959 7- Dec -10 3.89 2,177 79 5.22 2,379 1,964 8- Dec -10 4.18 2,231 60 5.71 2,416 1,847 9- Dec -10 4.23 2,119 69 5.84 2,441 1,694 10- Dec -10 4.29 2,277 54 5.89 2,427 2,031 , 11- Dec -10 4.01 1,977 65 5.40 2,399 1,457 12- Dec -10 4.21 ' 2,110 56 5.42 2,435 1,271 13- Dec -10 4.42 2,241 55 5.80 2,422 1,963 14- Dec -10 4.57 2,331 46 5.78 2,435 2,142 15- Dec -10 4.33 2,271 57 5.81 2,457 2,028 16- Dec -10 4.16_ 2,263 54 5.80 2,403 2,0 17- Dec -10 5.13 2,333 49 5.91 2,449 2,079 18- Dec -10 4.29 2,156 62 5.82 2,431 1,807 19- Dec -10 4.40 2,250 56 5.86 2,473 1,857 20- Dec -10 4.33 2,286 58 5.80 2,495 2,033 21- Dec -10 5.28 2,362 46 5.79 2,470 2,117 _ 22- Dec -10 4.95 2,348 47 5.87 2,477 2,091 23- Dec -10 4.58 2,335 57 5.88 2,471 2,097 24- Dec -10 5.01 2,341 48 5.89 2,459 2,080 25-Dec-10 4.95 2,333 51 5.80 2,429 2,077 26- Dec -10 4.55 2,325 55 5.89 2,456 2,069 27- Dec -10 4.88 2,312 47 5.84 2,426 2,052 28- Dec -10 4.80 2,323 47 5.89 2,431 2,057 29- Dec -10 4.46' 2,293 56 5.88 2,445 2,048 '666'1 I49`Z 08'9 89 ZZ4`Z Z£'4 II- qaA -4I 6Z6' L 8L9'Z 18'9 69 99E'Z 91'4 It EZ6` I. E99 99'9 09 O£r`Z 46'4 _ TI-gad 4LZ`Z 199'Z 08'5 15 Z05`Z 16'4 II- ga3-IT 6LE`Z 9E8'Z 08'9 19 699'Z 9Z"£ II-gaI LLO`Z 906'Z Z£'4 99 999`Z Z1 £ II- - 6 _ OC9' I 0Z6'Z 96'9 1L 869`Z 59•£ II 6L0`Z L08'Z Z8'9 89 ZLE`Z 914 tt -L 801'Z 189`Z Z8'9 ES 494`Z LZ'9 tI - qaI -9 Z10`Z 61L`Z 08'9 19 144`Z 614 IT EL6` I 969`Z £8'S 89 46Z`Z OZ'4 It - qal - 4 1 90`Z 0Z9'Z L6'9 69 _ SZE'Z ZVI? II 1O0`Z LL9`Z 48'5 0L 48Z'Z LZ'$' II - Z - 966` 1 945'Z £9'9 IL ELZ'Z 8E17 it - ga3 - I . 688'1 1.99`Z 48'9 49 LO£`Z Z5'4 IT Uef - I£ 611`Z OE9'Z 98'9 Z9 09E'Z 64'4 II OS 1`Z 8£9`Z 96'9 09 15£'Z L4'4 II Uef 840'Z IE5'Z L8'9 E9 L1E'Z 9Z'4 IT - 8Z OZ0`Z 0Z9`Z 6L'9 £S 54£'Z OZ17 IT Uef - LZ 901`Z ZZ5'Z 18'5 E9 11E'Z 41'4 IT uef l'0 6'Z - 8ZL`Z ££'4 49 06Z' OLT£ TT Uef - SZ ' 8E0'Z 94L'Z ££'b L9 _94E'Z 8E'E II 6/6'1 Z • ' `Z 9£'4 Z9 90£`Z L9'E II - £Z 1Z6' I. L84`Z 9E17 99 14Z'Z ME TT - ZZ OZl'Z 009`Z 9£'4 Z9 � E4£`Z EWE TI-uef-TZ _ E£1'Z 064`Z 6E'4 09 Z8E`Z LL'E IT M.'Z 4L4`a 9E1 09 19£`Z LL'E II uef Z1Z'Z 69t`Z 19'9 64 L8E'Z 9£'9 ti _ 6Z1'Z L 15'Z 18'9 89 1L£`Z 45'4 TI- Uef -LI L8L` I. 1L4'Z 8L'9 ES 98E'Z OZ'9 II- uef-gt E61 849'a 9L'9 Z9 81VZ L4'r It Uef - SI 101`Z I05'Z 08'9 45 6LE'Z 9L'4 II- uef -VI 181'Z Z05`Z 08'9 09 1LE'Z £a'4 IT -uef - Et 59Z'Z LL"Z 80'5 E5 814'Z 9417 II - Zt 80Z'Z EZ5`Z 8L'9 84 PM 1L'4 It- uef 111'Z OZ5`Z 08'5 45 99E`Z 6917 Tt uef ZOl'Z Z5l`E 18'9 09 4Z£'Z 8£'4 tT - uef - 6 ZL6' I. ZL4`Z 48'5 L5 EZE`Z £ 1 TI - g 160'Z Z44`Z 01'9 05 61EZ fair Tt - uef -L LE1`Z _9E1'Z £8'S L4 9£E'Z 89'4 _II LLO`Z 9WZ 11'5 4S Z6Z'Z 9Z'4 II - uef - S LLO`Z £51'Z 8L'9 45 11E'Z 6Z17 Tt - Uef - 4 8Z6` 1 Z84`Z 08'9 Z9 9EZ`Z L9'£ TI - Uef - £ 040'Z _4Z4'Z L£'4 4g L8Z' Z EEC II - Uef - Z LO1'Z 994`Z 01'9 94 £0£'Z Z£'4 II - Uef - I — L11'Z Z5"Z 99•5 ES 56Z'Z 64'4 OT - IE_ 601'Z 44r`Z 18"5 9b 91£'Z 69'4 0I • 0 190`Z 91L'Z 9£ 09 991`Z £L'£ II SZO'Z 989`Z ££'4 49 OL£`Z 08'£ TI-Jdy £LO`Z £89'Z ££ 99 996`Z 08'£ TI-JeW-IE L. *`4 LLL`Z E£'1 99 94E'Z ZEE II 4£8`4 4L£'Z ZZ'1 99 864'Z LO17 II-JeW-6Z Z -48`4 49E`Z £E1 99 94Z'Z 96'£ ii - 8Z 1Z6` 4 699`Z ££17 69 4Z£`Z 18'£ TI-JeI LZ 018' 4 06E`Z 9£'4 Z9 ZOZ'Z EWE It-Jet/4 1717E 4 001'Z ££'1 179 Z IZ`Z £017 IT 178/.` I. 48E`Z 98'9 49 ZEZ`Z L91: II 6L8` 4 9Z1'Z 9L9 1.9 80£`Z 96'£ TT 846` I. 991`Z £8'9 - L9 ZZ£'Z E91: II - ZZ 188` I. £11`Z 89'9 Z9 _ 96Z'Z Z617 TT 906' 4 06£'Z L9'9 09 1LZ'Z 84'b II-JeW-OZ L98'1. 191'Z £8•9 49 £8Z'Z 49' _IT JeW _ L 46' I. Z94`Z 49'9 Z9 9£E'Z 8E'4 II - 8T 016' 4 £09'Z 18'9 49 Z1Z'Z 9Z17 _II - LI 6E6'1. £L4`Z 48 "9 49 44£`Z E8'4 IT JeW-Ji OZ6' 1 LL1'Z £8 99 90£'Z Z9'1 TI - ST 8L8` 4 449'Z Z9'9 £9 4£Z'Z 9E17 II _ L86' 4 609'Z Z8'9 49 ZLZ' L917 It JeW - ET 0Z0`Z 949`Z 178'9 49 L4Z'Z 64'1 II JeW - ZI 940`Z 849'Z £8'9 Z9 10£'Z 99 TI-JeW -II _ 446`4 499`Z Z8'9 �L9 t'Z£'Z 49'4 TT JeW 190'Z 919'Z 98'9 69 1££`Z L417 II-JeW-6 Z90`Z 464'Z 9E17 1.9 94£ 9017 IT - JeW - 8 916'4 609'Z 08'9 49 96Z'Z 0417 TI-JeW-L 060`Z 489'Z 6L'9 Z9 9L£'Z 04 7 It -Je141-9 890'Z 8 08'9 61 8L£'Z LZ•1 II-JeW -S 9Z6' 4 1+49`Z LE17 09 179£'Z 66'£ _II -JeW 196' 4 0Z9'Z L£'1 99 81E'Z 10'1 II -E 614`Z 499`Z 9£17 89 - COP' Z 179'£ IT- JeVN-Z ZE6' 4 199'Z 1'1 1 _ Z 9 Z9£`Z 06'£ TI JeVN-I 484'Z 009'Z Z£1 E9 £6£`Z 16'E II-gaJ-8Z — L94'Z £99`Z 00'9 19 L11'Z 8Z17 IT Z 94`Z 9L9'Z 4Z17 69 0O1 66'£ II gad 0£4`Z 199'Z 9£ 81 0£1'Z 96 Ii qa4 - SZ Z 94`Z 1769`Z 9E17 99 644`Z 96'E TI gal 66£'Z 699'Z 4Z17 L1 609'Z Z017 IT1al - 066'1 Z£L`Z Z£17 09 461!`Z EWE II gad _104'Z 419'Z ££'1 99 Z01'Z 16'£ II - IZ . E0 1 4E -4 1£17 £S E44`Z Z017 Ti gai-OZ 048'4 ZZ9'Z L£17 L1 941'Z Z417 II _ 466` 919`Z 1£1 69 PLE'Z 66'E ii - 8I 191'Z 9Z9'Z 9£17 91 8Z1`Z 96'£ TI gad Z46' I. ZL9`Z 6E ZS 0E4 L6'£ TI Z86' 4 LZ9'Z 48'9 99 L11'Z £L'1 II IP • • • 3- Apr -11 3.99 2,382 61 5.78 2,787 2,005 4- Apr -11 4.08 2,284 54 4.32 2,411 1,915 5- Apr -11 3.83 2,304 58 4.32 2,432 1,864 6- Apr -11 4.08 2,319 56 4.32 2,461 1,903 7- Apr -11 4.13 2,277_ 46 4.32 2,422 1,905 8- Apr -11 4.49 2,329 46 5.77 2,468 2,009 9- Apr -11 4.38 2,305 49 5.83 2,451 1,912 10- Apr -11 4.75 2,313 55 5.82 2,456 1,881 11- Apr -11 4.92 2,288 48 5.81 2,427 1,912 12- Apr -11 4.95 2,313 55 5.83 2,496 2,032 13- Apr -11 5.06 2,316 52 5.82 2,458 1,959 14- Apr -11 5.13 2,288 50 5.82 2,442 1,889 _ 15- Apr -11 4.89 2,271 54 5.81 2,438 1,785 16- Apr -11 5.35 2,288 51 5.80 2,453 1,921 17- Apr -11 4.72 2,194 _ 55 5.83 2,445 1,894 . 18- Apr -11 3.92 2,401 58 5.80 2,731 2,090 19- Apr -11 3.60 2,435 58 5.80 2,750 2,105 _ 20- Apr -11 3.61 2,424 59 6.04 2,843 1,753 21- Apr -11 2.93 2,443" 59 4.31 2,915 2,148 22- Apr -11 3.97 2,306 63 5.79 2,464 2,064 23-Apr-11 4.18 2,338 74 5.81 2,501 1,892 24- Apr -11 4.50 2,407 81 5.80 2,662 2,023 25- Apr -11 4.34 2,404 62 5.81 2,753 1,992 26- Apr -11 4.37 2,319 56 5.79 2,494 1,787 27- Apr -11 4.29 2,322 57 5.78 2,568 1,976 28- Apr -11 1.89 2,100 72 4.04 2,353 1,680 29- Apr -11 5.07 2,319 58 5.81 2,442 2,059 30- Apr -11 4.84 2,351 59 5.78 2,460 1,999 1- May -11 3.94 2,397 57 5.57 2,771 2,097 2- May -11 4.40 2,367 59 5.76 2,528 2,079 3- May -11 3.71 2,388 62 5.08 2,667 2,082 _ 4- May -11 3.44 2,375 60 4.35 2,513 2,112 5- May -11 3.90 2,360 62 4.35 2,471 2,213 _ 6- May -11 3.77 2,375' 52 5.78 2,651 1,875 7- May -11 3.86 2,367 56 4.36 2,816 2,059 8- May -11 4.00 2,298 57 4.37 2,436 1,958 9- May -11 3.95 2,214 61 4.35 2,450 1,946 10- May -11 3.99 2,305 60 4.35 2,451 1,958 11- May -11 3.93 2,287 60 4.34 2,440 1,936 12- May -11 3.80 2,241 62 4.35 2,423 1,977 ^ 13- May -11 5.06 2,290 51 5.85 2,451 1,905 14- May -11 4.25 2,247 58 5.80 2,462 1,975 15- May -11 3.74 2,226 58 5.83 2,495 1,894 _ 16- May -11 4.19 2,158 71 _ 5.82 2,541 1,901 17- May -11 4.01 2,132 66 5.81 2,572 1,793 18- May -11 4.16 2,166 67 5.93 2,516 1,870 19- May -li_ 4.28 2,169 66 5.88, 2,481 1,828, H • • 20-May-11 4.02 2,155 65 5.73 2 4 7 y 5 3 3 1,83 4 21- May -11 3.92 2,197 59 4.37 2,441 1,740 22- May -11 3.88 2,325 52 4.36 2,391 1,943 23- May -11 3.82 2,033 65 4.37 2,373 ' 1,706 24-May -11 3.88 2,049 72 4.35 2,420 1,727 25- May -11 3.93 2,085 68 4.34 2,338 1,785 26- May -11 4.01 2,092 66 5.79 2,351 1,816 27- May -11 4.47 2,126 59 5.83 2,317 1,797 28- May -11 4.35 2,089 59 5.85 2,358 1,757 29- May -11 2.10 2,701 67 5.81 3,878 1,850 30- May -11 2.93 2,772 65 5.93 4,311 1,810 31- May -11 3.98 2,147 50 4.33 2,258 1,925 1- Jun -11 4.17 2,068 62 5.82 2,402 1,783 2- Jun -11 4.68 2,185 55 5.83 2,395 1,837 3- Jun -11 4.29 2,073 67 5.82 2,407 1,807 4- Jun -11 3.77 1,928 83 4.34 2,343 1,684 5- Jun -11 4.23 1,939 78 5.91 2,357 1,583 I 6- Jun -11 4.49 2,013 71 5.83 2,352 1,627 7- Jun-11 4.42 1,995 68 5.83 2,363 1,607 8- Jun -11 3.95 2,041 58 4.38 2,211 1,798 9- Jun -11 3.95 1,984 65 4.33 2,236 1,612 10- Jun -11 4.07 1,898 85 5.82 2,287 1,282 ` 11-Jun-11 � 4.84 1,967 53 5.83 2,139 1,423 12- Jun -11 5.12 2,002 51 5.83 2,247 1,282 13- Jun -11 4.55 2,060 49 5.82 2,254 1,834 14- Jun -11 4.29 + 1,915 63 5.84 2,282 1,561 15- Jun -11 4.98 2,056 53 5.82 2,180 1,809 16- Jun -11 4,59 2,037 54 5.83 2,172 1,850 17- Jun -11 5.06 2,042 54 5.83 2,180 1,837 18- Jun -11 4.14 2,025 66 5.80 2,243 1,865 19- Jun -11 4.75 2,028 54 5.84 2,156 1,832 _ 20- Jun -11 4.06 2,002 60 5.02 2,185 1,806 21- Jun -11 5.05 2,036 54 5.84 2,146 1,872 22- Jun -11 4.39 2,001 52 5.83 2,122 1,883 23- Jun -11 3.94 1,959 61 5.10 2,238 1,579 24- Jun -11 3.84 1,941 67 4.33 2,190 1,643 25- Jun -11 4.16 1,943 55 5.83 2,154 1,377 26- Jun -11 4.15 1,871 85 5.83 2,300 1,580 27- Jun -11 4.46 1,979 58 5.85 2,242 1,653 28- Jun -11 4.44 1,881 58 5.84 2,178 1,581 29- Jun -11 4.46 1,929 60 5.85 2,234 1,359 30- Jun -11 4.28 1,777 86 5.84 2,241 1,507 1- Jul -11 4.88 2,029 55 5.84 2,214 1,814 2- Jul -11 5.36 2,045 51 5.83 2,178 1,885 3- Jul -11 4.28 2,006 66 5.84 2,240 1,799 4- Jul -11 4.76 2,010 60 5.84 2,231 1,795 5- Jul -11° 4.28 1,967 60 5.85 2,212 1,654 • • 6- Jul -II 4.82 2,045` 56 5.82 2,200 1,868 7- Jul -11 4.21 1,994 55 5.82 2,197 1,791 8- Jul -11 4.08 2,003 62 5.81 2,268 1,731 - 9- Jul -11 4.13 2,095 59 5.84 2,242 1,945 10- Jul -11 3.96 2,086 60 5.80 2,257 1,882 11- Jul -11 4.41 2,060 58 5.81 2,239 1,481 12- Jul -11 4.00 2,056 53 4.30 2,152 1,922 13- Jul -11 4.72 2,087 58 5.80 2,356 1,605 14- JuI -11 0.00 0 0 0.00 0 0 15- Jul -11 4.04 2,125 63 5.81 2,283 1,765 16- Jul -11 3.63 2,026 61 4.36 2,107 1,896 17- Jul -11 3.95 2,044 58 4.35 2,159 1,892 18- Jul -11 3.79 2,027 56 5.80 2,107 1,904 19- Jul -11 4.09 2,022 53 4.30 2,117 1,921 _ 20- Jul-11 4.02 2,017 57 4.35 2,116 1,877 21- Jul -11 4.12 2,020 54 4.35 2,110 1,898 22- Jul -11 4.06 1,988 61 5.81 2,293 1,596 23- Jul -11 5.18 2,071 55 5.83 2,170 1,920 24- Jul -11 4.11 2,016 54 4.35 2,095 1,914 25- Jul -11 3.71 2,182 56 4.35 2,504 1,900 26- Jul-11 3.85 2,124 58 4.35 2,366 1,884 27- Jul -11 3.97 2,298 63 5.82 2,472 1,969 28- Jul -11 3.90 2,238 60 5.83 2,440 1,928 29- Jul -11 5.06 2,105 57 5.83 2,213 1,911 30- Jul -11 4.20 2,025 79 5.83 2,225 1, = +•3 - _ 31- Jul -11 4.15 1,995 80 5.83 2,206 1,838 1- Aug -11 4.58 1,998 71 5.83 2,185 1,843 2- Aug -11 4.39 1,981 77 5.84 2,214 1,760 3- Aug -11 4.14 1,911 91 5.84 2,174 1,687 4- Aug -11 4.89 1,969 62 5.83 2,154 1,597 5- Aug -11 5.07 2,026 54 _ 5.80 2,094 1,898 6-Aug-11 � 4.58 1,942 71 5.83 2,160 1,617 7- Aug -11 4.29 1,803 87 5.84 2,178 1,585_ 8- Aug -11 4.19 1,815 83 5.84 2,157 1,520 9- Aug -11 4.10 1,915 64 5.83 2,104 1,410 10- Aug -11 4.12 1,952 58 5.83 2,115 1,595 11- Aug -11 4.42 1,972 55 5.83 2,148 1,669 12- Aug -11 4.38 1,837 71 5.82 2,144 1,478 13- Aug -11 4.40 1,890 67 5.82 2,139 1,544 14- Aug -1.1. 4.12 1,827 81 5.77 2,169 1,517 15- Aug -11 4.13 1,841 78 5.82 2,153 1,491 16- Aug -11 4.45 1,845 71 5.81 2,161 1,460 _ 17- Aug -11 4.28 1,806 74 5.81 2,142 1,404 _ 18- Aug -11 4.45 1,878 66 5.83 2,141 1,525 19- Aug -11 4.72 1,985 54 5.84 2,113 1,672 20- Aug -11 4.46 1,956 56 5.84 2,138 1,681 21- Aug -11 4.16_ 1,889 65 5.831 2,155 1,560, 0 • 22- Aug -11 4.14 2,007 56 5.81 2,145 1,694 23- Aug -11 4.12 1,897 68 5.83 2,152 1,604 24- Aug -11 4.94 1,966 60 5.82 2,151 1,581 25- Aug -11 5.04 1,985 54 5.83 2,129 1,748 26- Aug -11 4.85 1,960 62 5.83 2,164 1,510 27- Aug -11 4.72 1,960 69 5.82 2,289 1,546 28- Aug -11 4.17 1,799 67 5.84 2,151 1,090 29- Aug -11 4.55 2,035 62 _ 5.82 2,243 1,792 30- Aug -11 4.58 1,856 72 5.83 2,169 1,467 31- Aug -11 4.47 1,876 75 5.83 2,175 1,611 1- Sep -11 4.30 2,013 57 5.83 2,876 1,605 2- Sep-11 4.63 1,933 78 5.83 2,330 1,586 4.66 1 884 65 3- Sep -11 5.83 2,170 1,156 4- Sep -11 4.41 1,809 71 5.84 2,191 1,320 5- Sep-11 4.47 1,980 65 5.84 2,164 1,774 6- Sep-i1 4.53 1,959 60 5.83 2,178 1,737 7- Sep-11 4.02 2,015 51 4.35 _ 2,088 1,921 8- Sep-ii 4.06 2,001 53 4.35_ 2,098 1,859 r 9- Sep -11 3.89 1,935 62 4.35 2,251 1,624_ 10- Sep-11 3.99 2,059 58 4.35 2,161 1,931 11- Sep -11 4.35 2,066 54 5.82 2,157 1,928 12- Sep -11 4.16 2,122 73 5.81 2,354 1,927 13- Sep-11 4.49 2,049 57 5.81 2,143 1,938 14- Sep-11 4.12 2,028 74 5.52 2,153 1,906 15- Sep-11 4.37 2,080 70 5.81 2,334 1,943 16- Sep-11 4.32 2,078 74 5.80 2,181 1,895 17- Sep -11 4.79 2,086 64 5.81 2,206 1,949 18- Sep -11 4.39 2,060 61 5.82 2,193 1,854 19- Sep -11 3.97 2,029 56 4.33 2,107 1,798 20- Sep-11 4.33_ 2,066 56 5.51 2,431 1 ,795 21- Sep-11 4.09 2,053 62 5.76 2,392 1,87 22- Sep-11 4.10 2,019 56 4.34 2,099 1,787 23- Sep-11 5.40 2,079 57 5.82 2,177 1,822 24- Sep-11 4.50 2,033 63 5.81 2,120 1,751 25- Sep-11 4.46 2,008 55 5.82 2,107 1,789 26- Sep -11 4.96' 2,077 60 5.81 2,194 1,855 27- Sep-11 4.93 2,040 62 5.82 2,168 1,801 28- Sep-11 4.42 1,964 68 5.81 2,244 1,547 29- Sep-11 5.41 2,073 54 5.80 2,154 1,864 30- Sep -11_ 5.29 2,049 51 5.81 2,152 1,827 • • Attachment 2: Monthly Infection Totals and Waste Stream Summary Monthly Injection Totals Volume of Month Injected Fluid (BBLS) October 2010 49788 November 2010 54450 December 2010 49512 January 2010 53511 February 2011 52921 March 2011 51660 April 2011 49581 May 2011 57437 June 2011 48760 July 2011 45221 August 2011 69142 September 2011 48773 Page 1 of 1 • • �� Attachment 3: Waste Stream Summary Physical, Chemical and Other Relevant Characteristics of the Injected Fluids • Incidental non-hazardous wastes Wash water seawater gene��dby module opoo�iono& ' Waste characterization aamp|in Utility modules sump maintenance for drilling mud make-up, completed and verified not sampling fluids ° Incidental equipment leaks potable water chemical hazardous -Gane��rhn additives. Pmoeuuoontm|iu knowledge o Additives for Reverse Osmosis &potable strictly m - intained used water systems Waste characterization sampling G�coVhe�gexchongo °«ehic � u&a q ui p me»t(a»d � eaza ) Glycol (MEG, DEG, TEG, oump|o�dO0-11'11 and veh�ednot media °Modu|eondfooi|ityheuUnQandcoo|inQ propylene) ' ' ' RCRA-hazardous - Generator systems knowledge used Non-exempt spill ° Fluids neuuvo�d�nmo|eanupofnon- VVa��enmw.grm�|.v�th VVou�nho��*hza�onaamp|in clean-up hydmuarbnnorchemical -~-,~~~~'----~~'~'-' Spill products '---- Generator knowledge o Gpi used Water, glycol possible Hydm�ufluid °P�uauna�anewornon'oxomptpmneoopmduct�mid'u|inoxioting VVoa�«hano�*r�aU»»uamp|inQ test residual completed and verified not RCRA' (water or glycol only) lines, vessels lines, traces ' ' hazardous other biocide Boiler blowdown ° Rig or production facility boilers Water Not injected year hz date, fluids used for drilling mud make-up water Off spec product Varies • Products spilled, out-dated or no longer Variou - MSDS reviewed Not injected year to date acceptable for original purpose Contained snow/ ° Outdoor containment around fuel and Water, possible traces of Waste characterization sampling pnndedwater chemical storage tanks hydmoarbonnr chemicals if c»mP��o and «erm*o o Dopmooiunuonorbabwaenpadu&modx MhemhavabaenupiUo ��---- ----- knowledge used ° Motor oil Routine verification sampling conducted to confirm not RCRA- Lubrication oil • Transmission fluid Hydrocarbons/water mixes hazardous - Typically sent to • Hydraulic oils hydrocarbon or offsite recycle • Internal or external wuohdown of skids, modules Waste characterization sampling Non-exempt facility ° Equipment cleaning (using non- VVater traces »f completed and verified not RCRA' wash water hazardous detergents urdegreasers) hydmcorbo»'ch«miva|»' hazardous - Generator knowledge detergent • Residues removed from RCRA-empty used containers Waste characterization samplirig Incinerator ash ° Trash and ummpwo�a Particu|ateu/RCRAmeta|o completed and verified not RCRA' • Sewage sludge hazardous Domestic • Camp wastewater treatment plant(s) and VVater, soap residuals, human Generator knowledge used to verify wastewater/ sludge site enviro-vacs waste not RCRA Waste characterization sampling • Saline concentrate from reverse osmosis Reverse osmosis completed and verified not RCRA- concentrate/seawater pmc»«»formahi»gP�ub|*wabar�om Saline water hazardous - Generator knowledge seawater used Notes: 1. Similar wastes may be RCRA exempt, depending on waste- enerating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 • • Attachment 4 United States Environmental Protection Agency A' el -,n, �; � � ; Region 10 I . S.r >�.r:� x{ 1200 Sixth Avenue, Suite 900 ,-47.tw °'%." Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e-mail: cutler.thor@epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility 1 Well I Permit No. PTD No. Pioneer - Oooguruk Unit ODSDW 01 -44 AK- 1I009 -A 207 -140 Injector MIT Type Test Type Test Date Class I T X IA Std. Annular Pressure Test (SAPT) Jan t• 2011 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval !Comments Presssure (psi) test TVD) 3,500 Diesel 5,035' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or St during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T / �ST � ART TIME: RECORDED PRESSURES (PSI) RESULT E WW 00`ai /pm PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN P/F S TUBING s7,1'1,6 Liz 27-53 1—ti34 Pass/fail T INNER ANNULUS ti •z] SS t• 352.5 36"(5 T'l'° OUTER ANNULUS 7._..r. 1 VI. • (0 34 • H 1 COMMENTS: 1 1 r> 9w•t, '354 I — 3S2.3 i «%$ cowC tS hs T START TIME: RECORDED PRESSURES (PSI) RESULT . E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS _ 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN 9 TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: IMISC COMMENTS: Initial MITIA as Class I well with rig (witness T.Syed), to 4,970 psi and tbg to 5000 psi - 1/27/08. Last tested MITIA January 17, 2010 (Thor Cutler witness with Tom Tredway) last test in 2010, pressure loss was 118 psi in 30 minutes, (tested at 4170, higher than required 3500 psi level ) NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start. MIT over if: 1) Total toss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of lass during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on - site decision per Inspector). 1 ( -- E -mail this MIT Test Data Fonn to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: a tor ep: Thor Cutler/Talib Syed Li al: v `""r �r r 7-, ,..._fi_e___„ , .0 S Attachment a chment 5 • 11 10 ..,...-- __---- 9 ----- ---' -- :----:1 --- -- — , -- 4:b , ,, u - --7--- ;_o v i - .7 -- 0 , 0 ' ' • - 0 # ' - : ' "' ' 0 ' ' -\,' - -- - t I •1 ±.. 1 ': ' 'Z • 4 '• , '‘r / / 17 I: ; / / / ' ' . . 0 - I 1 1 - 1 1' 1 1 1 I li ' F 1 f '1 -' C 1( NAlif ii ■ ' 11 1-1 Il a , 1 1 Ni i , ( to I- se i lat Ivi l „„i , la III • , , I. \ -,-, .,-;, vopuo,.A.0„,,,, 'VP ■ , \ ,,„ , 00 \,0‘_____--0 ', •,', '\ - • ‘,-„ ../,'-, , 0 \,0 -- C o ' , e , \ ' ,, , ,„ , , I IINIP ,: ,__,' ,.. . 7 --- , \ • ',.., - '' \\ --' ,-, ' ' - s '•-‘,. ---1--^---- ..... 00St all • , ,. \ _ , ‘. \ , 2 ,- , , ,,, :::,.__;__ '-'-`-, ' . Otici - a - awes . , -.-i _ _. , ga _ - ,, 00 "--.\\-, ,- , N■,- • -', -' 900z __ .„ , •--.,-. .' - ir - -- _ , • -\'. -•"--:-.'"'-';',•.'''- . - C' . . - - -, - - ---- --d• ' --- __: S asiii„._ ' ' - :-.•"„•:,---, ' .., -, ,, . , • ' -- -- --/- — --J- ---_- --„, - - --- t' - - --Q 0 Si ' , ‘-- 1 - - - --- -- ._-_-: . 141 44, 440444140. 1140 /NOL.J■nriumm.... 0 alogl_. -, .............. Pr ■•■-- (1/16/20119:15:17 AM) 3541 psi (1/16/2011 9:45:24 AM) 3520 psi -21 psi (0 days, 00:30:071 4000 • j IA — f=nd I est 1 -1000 2300.0 rt TUBING I w rt rt rn 1500.0 OA I : - f .- 7:50:00 AM 8:24:00 AM 8:58:00 AM 9:32:00 AM 10:06:00 AM 10:40:00 AM 1/16/2011 1/16/2011 1/16/2011 1/16/2011 1/16/2011 1/16/2011 192.168.124.52:PI_41001 [Cyclic] ODSDW1 -44 Pressures Oct 1, 2010 through Sep 30, 2011 5000 4500 4000 • 3500 3000 rr sv n 2500 I i 2000 A 1 I 1 1I 1 , 11 II I I 1_ L I I!11 , 1500 ' 1 I I 1000 I • 500 I t 1 _ I III 1 0, 7 70 7 0 7 0 7 7 0 714,.7 71;4 , 7 ! , �1 '1 ,?4,7 , )447 ' vett,. , , WHP BOA -IA 0 0 M. PIONEER OCT 29201u NATURAL RESOURCES ALASKAasis Menge Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 October 26, 2010 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2009 -2010 Annual Performance Review for Oooguruk Unit DW -1 Dear Commissioner Norman: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW -1), in accordance with Alaska Oil and Gas Conservation Commission ( AOGCC) Disposal Injection Order No 31, Rule 6. This surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by November 1 of each year and include data sufficient to characterize the disposal operation: • Pressures and injection rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW -1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, summarized, and included in this report for dates from July 1, 2009 through September 30, 2010. DW -1 Injection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from one - minute readings during injection periods; additional raw data can be provided upon request. Attachment 6 is a graphical representation of the tabular data. Oooguruk Development Project DW- 12009 -2010 Annual Performance Report October 26, 2010 Page 2 DW -1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. Attachment 3 includes a summary of physical, chemical, and other relevant characteristics of injected fluids. Assessment of Fracture Geometry No additional assessment has been completed since the modeling done in June 2008 that supported a 6 bpm injection rate and 14 ppg. Description of Anomalous Injection Results One anomalous data point was realized during this reporting period. On March 12, 2010 a rate of 8 barrels per minute occurred. The total injection period prior to pump shutdown was 6 minutes. The average rate for the first 5 minutes was 1.5 bbl /min. During the last minute of injection, the rate spiked to 8 bbl /min and pumps were shut down for a total of 3 minutes. Pumping resumed for another 132 minutes at an average of 3.5 bbl /min. Please note that the pumps used with this well are used on other operations when not needed for injection into the disposal well, therefore these periods of use were removed from the data set. Calculated Zone of Influence for Injection Fluids No changes have been made since Pioneer submitted a model in June 2008 that supported the current injection rate of 6 bpm. The Zone of Influence is still considered to be similar to modeling conducted for this disposal operation. Other Attachment 4 is the test form from the EPA and AOGCC- witnessed mechanical integrity test that was conducted on the inner annulus January 17, 2010. Attachment 5 is a copy of the circle chart from the above test. If you have any questions or require additional information, please contact Tim Crumrine at (907) 343 -2184 or tim.crumrine@pxd.com. Sincerely Vance Hazzar Drilling Manager - Alaska Enclosures: Attachment 1: DW -1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals Attachment 3: Waste Stream Summary Attachment 4: MIT -IA Test Form Attachment 5: MIT -IA Test Chart Attachment 6: Pressure Plot of Injection Data Average Average Maximum Maximum Injection Injection Average Injection Injection Minimum Rate Pressure Temperature Rate Pressure Injection Date (bbl /min) (psi) ( °F) (bbl /min) (psi) Pressure (psi) 65 ,965,61 2- Jul -09 3.81 1,813 65 4.45 1,994 1,604 3- Jul -09 3.51 1,648 63 4.47` `:. 1,84 u: 2 4- Jul -09 3.63 1,762 69 4.46 1,948 1,527 1,815 67 4.47 a 1,654 6- Jul -09 3.96 1,797 58 4.50 1,943 1,598 I - 09 3.64 67 4.48 }x: °.1,977 '? 1,562 8- Jul -09 3.43 1,799 66 4.48 1,980 1,607 9- Jul - 3.44 1,751 70 4,4$ 1,981 X415 10- Jul -09 3.39 1,835 73 4.48 2,015 1,692 .�- Jul -09 3.79 1,838 64 4.48 '- 1,994, 1,;4 12-Jul-09 3.80 1,800 62 4.48 1,952 1,486 1Ju1 -09 3.89 54 4.48 1,908 1,490: 14- Jul -09 4.04 1,787 52 4.47 1,955 1,334 .. ... j5- tut -09 . . .: 3.76 1 61 4.46 ;; 1; % 16-Jul-09 1.00 1,458 62 1.08 1,553 1,353 ! 23 59 4.47 17-Jul-09 $9 �``. , ,1,98;` 1,289 18- Jul -09 3.29 1,817 64 4.45 2,014 1,640 19- Jul -09 0.00 0 0 20-Jul-09 3.81 1,842 78 4.49 2,195 1,304 21- 1u109., 8�.:° 1,936 ��.`75' 4.54'` 1,640 22- Jul -09 3.92 1,825 58 4.53 1,972 107 23- Jul -09 3.92' 1Y852 59 4,t 9,962 : 2 24 -J u 1 -09 3.84 1,832 50 4.53 1,940 1,574 25- Jul -09`'` 3 1,782 74 4.50 2, ,.,.. 45 26-Jul-09 3.79 1,772 57 4.49 1,926 1,401 tut 09 3.81, 59 4.49 1,9 28- Jul -09 3.89 1,759 62 4.51 1,976 1,454 29- Jul -09 ,_. 3.88 1,793 71 `;'4.50 h : 1,961 30- Jul -09 3.73 1,728 64 4.50 1,884 1,381 3�- Jul -09 8 ;' 1,840 55 4.49 - 1, 1- Aug -09 3.89 1,783 60 4.53 1,941 1,485 2- dug -09 4.06 _10 54 4 £N 1,913 7 5h 3- Aug -09 3.86 1,762 70 4.49 1,950 777 4- Aug -09 1,810 68 4.49 s 2yfi302 5- Aug -09 3 .... 1,778 68 4.48 1,998 1,588 6- Aug -09 3:84 ` 1,794 65 4.49 n '2,043 11 7- Aug -09 3.83 1,614 67 4.47 1,997 14 8 dug -09 3 y:..:. 1,853 ;..., . 66 4.53 r., 2,085 ', 1,617 9- Aug -09 3.90 1,800 63 4.54 1,952 1,559 10- A"ug -09 3.92 ! . x;814 52 943 2 11- Aug -09 3.85 1,795 59 4.55 1,977 94 12 -A ` 4.08 1,815 50 ` 4.51 �, , 4 1,453' 13- Aug -09 3.65 1,770 56 4.48 1,923 1,280 14 -Aug* °'' .. 1,830 ` r 85 4.44 2,209: 1,193 15- Aug -09 3.24 2,019 80 4.45 2,284 1,735 16- Aug -09 3.73 1,629. 54 4.47 'a`'H 2,073 .... , -76f i u 17- Aug -09 3.77 1,876 60 4.52 1,989 1,589 ,Aug -09 3.86 1,816 5 4.51 1,6 a , y 1,390 19- Aug -09 3.93 1,855 57 4.51 2,004 1,447 20 -%� __ . w r 'x.64 1;99 : 53 4.5'f :.. 'f,� „ 31 21- Aug -09 3.95 1,845 59 4.49 1,964 1,329 227Aug -09 3.80 1,861 61 4.48 2,010,..; 1, .,., 23- Aug -09 3.86 1,843 64 4.48 2,026 1,598 24A 3.49 1,851, 55 ' 4.47 204 1,686 25- Aug -09 3.82 1,861 64 4.48 2,024 1,632 .z6- Aug -09 3.78 1;$17 72 449 1,986..: °� 1 27- Aug -09 3.56 1,815 59 4.50 2,000 1,544 9 . ' 3.72 1,818 : , 7 65 4.46 1,343: 29- Aug -09 3.64 1,814 70 4.08 2,008 1,574 30-Aug -09 3.81 x;827 59 4,41 2511 31- Aug -09 3.89 1,857 53 4.45 1,993 1,551 1- Sep -09 : °' 1,793 62 4.52 x,02 1,464 2- Sep -09 3.93 1,845 66 4.55 2,042 1,535 3 -Se -09 3.94 4,791 73 4.5 ` J` 47 4- Sep -09 3.91 1,835 63 4.48 2,042 1,506 5- Sep -09 3..94 1,877 65 � 4.50 2,0?.,' w ` X1;663 6- Sep -09 4.05 1,878 54 4.52 2,015 1,608 7-S 3.84 1,80 59 4.52 x',00 t 1,533 8- Sep -09 3.57 1,804 62 4.52 2,030 1,375 9-Sep-09,,' - Sep -09 3.83 1,881 53 4.49 ' 1;993 10- Sep -09 3.84 1,898 65 4.49 2,213 1,520 11- Sep -09 ;3 ..' 1,881 61 4.50 n 2,013..; j.3 12- Sep -09 3.65 1,914 56 4.49 2,067 1,656 13- Sep -09 , 3.98 1,873 52 4.52 2,022 � ., .' 1 2 14- Sep -09 3.75 1,870 58 4.48 2,043 1,502 15 -Sep a ,, ='x.50 65 4; . .. x;084 1,4.35 16- Sep -09 3.77 1,844 67 4.46 2,045 1,447 p -09 3.80 ` 1,771 71 ` � 4.51 `F 1 9 1;494 18- Sep -09 4.00 1,830 51 4.50 1,968 1,527 19= Sep -09 3.89 ° 1,835: 62 4.49 1,974 ro a 81 20- Sep -09 3.85 1,861 55 4.57 1,981 1,612 - Sep -09 ' , x,79 1,860 65 4.53' 1,49 22- Sep -09 3.90 1,845 61 4.50 1,969 1,635 23= Sep -09 3:82 1,814 56 4.5 1,975 1,40 24- Sep -09 3.93 1,828 59 4.50 1,953 1,569 3.91 1,780 62 ? . 4.54 A3 . 1,4619 26- Sep -09 3.96 1,815 65 4.53 1,958 1,518 27- Sip -o' g 3.73 r -. 1,790 58 '455 >, . 2,012 1 28-Sep-091 3.85 1,812 611 4.521 2,060 1,440 Zg- Sep -09 3.84 1,886 63 4.51 b 031 , �� . 1,589 30- Sep -09 3.98 1,840 55 4.51 2,021 1,433 1- Qct -09 `3.9 P� 57 4.50 �0,987 1,549 2- Oct -09 3.85 1,861 50 4.51 1,990 6 . 3- Oct -09 3.97819 50 4.48 , . 2,014.'.:1,4 4- Oct -09 3.90 1,872 52 4.48 2,007 1,380 S-Q =2,65 1,923 62 4.52 . £ 1,327 6- Oct -09 3.44 1,996 64 4.48 2,264 1,655 r,, 7- Oct -09 "� . ,F . 1,881' 64 4.45 2,031: 994 8- Oct -09 3.57 1,901 58 4.51 2,123 1,729 9- Oct -09 ,:.� 3.96 1,885 53 ,:. 458 2,41 ..76 10- Oct -09 3.83 1,866 62 4.51 2,004 473 0 3.86 1,911 56 4.55 QO 2 12- Oct -09 3.19 1,488 62 4.49 2,307 253 13 0et.::70 1,877 59 4.58 2;1321 fi732 14- Oct -09 3.55 1,847 63 4.52 2,024 1,644 15- Oct -09 3.87 1,900 53 4.57 y 2,001 1, 1 16- Oct -09 3.80 1,839 65 4.48 1,995 286 17- Oct -09 , 3.6 1,846 53 ' 4.55 2,023 ".� 244 18- Oct -09 3.88 1,841 58 4.58 2,013 1,606 i94 3.70 1,819: 64 410 1;04 20- Oct -09 3.85 1,808 68 4.57 2,031 1,618 21- Oct -09 3.87 1,828 54 1,995 - " #,5� 22- Oct -09 3.69 1,800 60 4.57 2,016 1,421 23-1 Ck �.. ..3` 80 1,822 54 4.61 - 1690 24- Oct -09 3.61 1,797 60 4.44 2,001 1,368 25-0�tb4 1,761 62 4 o_ 1,993 4036 26- Oct -09 3.99 1,851 50 4.93 2,011 1,473 27- Oct -09 3.77 1,823 62 ` 5.10 ''% ' 1, w 1,12 1-4 28- Oct -09 3.78 1,878 56 4.46 2,009 1,658 29 x.84 1,673 50 4.46 9$5 1,48 30- Oct -09 1.36 1,734 57 2.99 1,893 1,505 3i,,-Oct-o9 0.00 0 0 0.00 0 � 1- Nov -09 3.72 1,894 67 4.80 2,024 1,520 2 -Nod 1,777 63 4.47 ." 5 -x 774 ms.µ 3- Nov -09 3.84 1,751 67 5.10 1,932 181 4 -NO75 ' 77 4 !, 1,801 61 5.13 , 2,,199 1;60 5- Nov -09 3.84 1,788 69 4.54 1,953 1,586 G- Nov -09 3.89 1,831 64' 4:49 , 1�1_� 14 7- Nov -09 3.63 1,851 64 4.47 1,979 1,491 3.62 1,83.4 84 ' 4.5( _2,0 1553 9- Nov -09 3.78 1,872 83 4.59 2,295 1,588 10- Nov -09 3.'80 1,817 81 &3` 1,985 1,4a 11- Nov -09 3.98 1,845 67 4.58 1,976 1,525 ,. 12- Nov -09 3� >.. ; 1,851 69 4.62 . 973 1,637 13-Nov-091 4.00 1,816 55 4.531 1,988 1,484 Nov -09 3.87 1,741 73ifl 1,994 15- Nov -09 3.88 1,853 60 4.52 2,005 731 Nov -09 4.09 t,892 47' 4.52 1,975 1,5 *6 17- Nov -09 4.03 1,870 47 4.52 1,930 1,184 8= 1ov -09 3.70,90 56 4.52 „' 2,06d 1,423 19- Nov -09 4.02 1,914 50 4.54 2,021 1,394 20 -N3ves` x :" 4:01 1,909 48 4x49 *2,013 7 21- Nov -09 4.04 1,937 47 4.50 2,042 1,413 -4 ov -09 3.84 1,898 59 4.52 2,065 1, 23- Nov -09 3.93 1,910 54 4.55 2,062 1,374 24 -N' „., u.' 3 81 1,888...: 55 4.58 `�5 1,374 25- Nov -09 3.94 1,779 64 4.52 2,057 1,432 26-No 48 4.5 2,fl3T" 135 27- Nov -09 3.84 1,886 53 4.56 2,070 1,604 28 Nov - 09 3.90 1,948 57 „ 4:49 ,. 2,099 ,. 1 29- Nov -09 4.14 1,925 49 4.52 2,056 1,538 BU= Nov -09 4.02 1,907 49 4.54 . 2,059 :� .<` 1,59 1- Dec -09 3.96 1,967 54 4.81 2,134 1,547 2 qc -09' 3.52.. k., 65 4.47 x,070` 1,08. 3- Dec -09 3.64 1,926 61 4.48 2,177 1,437 4- Dec -09 3.67 1,894 58 , 453 'w: 2,078 17 5- Dec -09 3.97 1,937 61 4.51 2,052 1,427 6-A 09 3.83 1,919 59 4.50.y 1,79 7- Dec -09 3.67 1,927 58 4.50 2,214 1,421 8-Dec-09 3:86 1. 60 4.48,057 9- Dec -09 3.39 1,917 65 4.47 2,057 1,484 10- Dec -09 " 3.92 1,922 58, 4. 2,039 xw 5 11- Dec -09 3.72 1,909 67 4.56 2,065 1,403 Fu - sec -09 3.87 1,927 60 4.48 2,068 1,fi24 13- Dec -09 3.67 1,961 65 4.48 2,080 1,750 14- ` 1,942 81 4:.57 2; l40 x,68 15- Dec -09 3.75 1,844 78 4.56 2,090 1,666 16- Dec -09 3,74 1,826 83 ; x.52 2,4 x..1,,61=: 17- Dec -09 3.89 1,829 69 4.52 2,012 1,584 " ec - 09 3.87" 1,806 61 4.50 1,9T 1,388 19- Dec -09 3.69 1,736 85 4.55 2,034 1,389 20- 6ec -09 02 1,847 60 x:49 2,004 , t,5 21- Dec -09 3.80 1,797 69 4.47 1,970 1,589 ec - 09 3.66 1,863 63 4.48 1, "` x,674 23- Dec -09 3.98 1,869 58 4.48 1,961 1,775 24-09 3.90. ,843 65 4 'f;977 ';, 25- Dec -09 3.80 1,839 62 4.50 1,987 1,554 26 -Dec -00 3 45 , . , 1,732 75 4.48 X12' 1, : 27- Dec -09 3.90 1,818 64 4.51 2,016 1,416 28- Dec -Q .v 7 . 1`,88T ` 54 4.48 „ ;t ~,2,01 1,766 29- Dec -09 3.72 1,892 58 4.53 2,000 1,764 3.92 1,916 65 31- Dec -09 3.57 1,775 59 4.48 1,990 38 1- tan -10 3.89 3 4 57 l " 2,003 2- Jan -10 3.98 1,891 58 4.53 2,026 1,671 „ 3- Jars -10 3.95 1,849 70 ` ^4.51 24 4- Jan -10 3.83 1,810 66 4.52 2,026 1,457 �.. : ;. 5- Jan -10 �� 3 . �'r 1,798 70 4.51 1,498 6- Jan -10 3.85 1,860 62 4.51 2,036 1,588 70 -30 , 3.77; 63 8- Jan -10 3.81 1,898 52 4.48 2,005 1,713 9 - Jan -10 77, 1,873 63 "_ 4.45 100 _ 1,72 10- Jan -10 3.80 1,863 66 4.50 2,051 1,650 11- n -10 3.88' 1838 67 4 4 1,567. 12- Jan -10 3.83 1,881 64 4.49 2,033 1,653 13- tan -10: , 3.88 1,832 61' - 4.47 2,005 .. 1,0 14- Jan -10 3.74 1,823 61 4.50 2,005 1,562 15- Jan -10 3.90 °: 1,852 ;x. 59 4:55' W49 1,656} 16- Jan -10 3.83 1,896 59 4.51 2,042 1,653 v; 17- Jan -10 3.96 1,853 ; 60 ,.w4.47�: 18- Jan -10 3.84 1,833 69 4.51 2,079 1,515 kan -10 3.82 " 1,824 74 4.50 2> ` 1,578 20- Jan -10 4.07 1,973 51 4.50 2,109 1,769 21. tx 10 3.85 „yri 73 4.49 : n, °; 2,082 7 22- Jan -10 3.92 1,864 64 4.49 2,079 1,427 23- Jan -10 3.98 1,935 59 4.52 2,090 1,0 24- Jan -10 3.97 1,813 81 4.51 2,099 1,517 25-Jan-10 3.99 1,895 61 4.54: : ; 2 1,661' 26- Jan -10 3.93 1,833 75 4.56 2,057 1,574 27- Jan -10 4.03 1,912 63 4.62 2,074 k;` 1; -. ,; 28- Jan -10 3.91 1,847 75 4.81 2,078 1,574 Haa -10 38.8 =$ `y _ 1,767 ° 7$ 4.49 X1 1,454 30- Jan -10 3.90 1,954 59 4.49 2,092 1,598 31- Jan -10 3.69 = `1,956 60 4;2 2,089 1- Feb -10 3.71 1,919 67 4.52 2,096 1,589 2. 7 3.89 55 4.48: 1,633: 3- Feb -10 3.95 1,883 66 4.49 2,130 1,629 4- Feb -10 3.95 1,907 54 ,4,48 2,0880 5- Feb -10 3.93 1,933 61 4.50 2,113 1,625 ~. , 6- Feb -10 � � ,;;�� > 1,930 61 ` 4.51 2,1 , 1,219. 7- Feb -10 3.75 1,882 64 4.49 2,113 1,447 8-Feb-10 "3.95 1,949 59 4.56 2,114 � 9- Feb -10 3.88 1,881 57 4.55 2,121 1,228 ;:fib 10 3 89 } . s 1,939 59 4.51 2,11 ... 1,552 11- Feb -10 3.90 1,923 68 4.55 2,125 1,585 12- Feb -10 3.81' °2,020 65 ;4.52 ?` 2,128 62 13- Feb -10 1.62 1,942 75 4.14 2,153 1,630 14 -Feb ,.. ,,. 3.79 1,482 82 4.48 M ,000:x >3sY 1,244 15- Feb -10 3.73 1,739 801 4.57 2,209 1,256 .. 16- Feb -10 3.82 1,786 69 4:5 2,144 . 1,1° 17- Feb -10 3.86 1,927 66 4.55 2,125 347 18- Feb -10 4.00 1,981 55' 2JO5 1,837 19- Feb -10 4.07 2,012 57 4.55 2,131 1,632 ri ,Feb -10 3.99 2,008 58 4.510 1,580 21- Feb -10 4.09 2,052 62 4.52 2,171 1,761 224eb -1 } ry ? 8 2,021 58 4 2,134 44 7 23- Feb -10 3.93 2,034 67 4.47 2,137 1,710 2Feb-10 3.93 1,991 64 4.47 1,730 25- Feb -10 3.88 2,003 65 4.51 2,136 1,710 6 -feb -10 4 CO .,:,',:�r 2,005 61 4.56 � 2,141 � � � 1,712 27- Feb -10 3.87 1,991 62 4.58 2,142 1,678 281<eb -10 4.07 .,A . 53 4.56 2,144 " {.1,7 u 1- Mar -10 4.28 2,010 59 5.87 2,182 1,629 2- Mar -10 3.91 1,967 62 5.64 2,130,.;' 1,1,,Q7 3- Mar -10 3.91 1,950 56 4.49 2,266 26 4- Mar -10 4.34 2,013 58 5.83 748: _ 5- Mar -10 3.91 1,907 59 5.55 2,477 30 '.,..� �$? 2,038 63 5.82 2 42 1,660: 7- Mar -10 3.92 2,001 58 4.49 2,118 1,379 8 - Mar - 10 �"`3.94 2,133 61 5.91 _`. ` 2,412 9- Mar -10 3.11 1,978 59 4.52 2,381 503 0- Mar -10 3.77 2,112 59 5.88 4 76 1,698 11- Mar -10 3.94 2,124 60 5.89 2,495 1,759 12- -10 3.66 2,1:3 66 8 x,448 17 13- Mar -10 3.30 2,147 66 4.49 2,582 1,716 14- Mar -10 3.11 2,140 67 4.50 ;, -; 2,7 80 `fi 7 15- Mar -10 37 2,095 65 4.53 2,616 1,776 16 -r -10 2.9T 2,1 fl 73 4.473519 1,660 17- Mar -10 3.05 2,111 58 4.48 2,396 1,740 18- Mar -1.0 7- 1,865 75 4 53 ...,.. 2,161 f,67 2 19- Mar -10 3.97 1,832 81 4.61 2,213 1,442 Mar -10 4.03 1,965 63 4.60 2,173 .�. r 1, , 21- Mar -10 3.82 1,962 62 4.63 2,182 1,539 221f 3.93 1,994 , x 62 4.56 x,203 1,701; 23- Mar -10 3.95 2,009 58 4.53 2,152 1,684 24- Mar -10 3:96 1,976 60 4.62 , 1 2,17783 25- Mar -10 3.86 2,004 63 4.50 2,180 10 3.85 2,036 64 ` 4.48 : X178 1,81;7 27- Mar -10 3.94 2,038 59 4.51 2,164 1,656 28- Mar -1 fI .` ;a` 1,973 53 4.48 213656 29- Mar -10 3.87 2,051 64 4.51 2,206 1,666 X30- Mar -10.. y „� 4.36 1,986 X 52.` 5.90 2;1.51 i' 1,5 31- Mar -10 3.65 2,022 60 4.45 2,255 134 2,100 , .f, 69 5.29 - „ , x;2,290 ` 1;64G 1 -Apps 2- Apr -10 3.64 2,120 62 4.49 2,422 1,681 3- Apr -10 .. 3.91 2,051 58 4.51 2,258 ,r.v 1, 4- Apr -10 3.88 2,049 60 5.96 2,319 87 r 5- Apr -10 1.09 1,684 68 "A.85 1,827 7 6- Apr -10 3.52 1,978 62 4.59 2,357 19 7 y �4pr -10 ..x. v 3.76 1,990 63 4.47 �'�' 2,187 8- Apr -10 3.31 2,039 62 4.50 2,316 1,609 97Apr -10 4. 199 ...:. 55 4.537 1,632 10- Apr -10 3.87 2,019 64 4.53 2,176 1,772 11 t"0 2,010" 64 4.47 2,187 12- Apr -10 3.79 1,959 68 4.48 2,214 1,634 13- Apr -10 3.86 1 ;95 69 `` 4s 2,200 1;. 14- Apr -10 3.69 1,966 65 4.47 2,209 1,672 15- Apr -10 3.84 2,028 64 , '4,48 2,M 2' 16- Apr -10 3.91 2,002 58 4.47 2,198 1,638 Apr -10 3.68 2,010 66 4.48 2,198 ., tv., 6 18- Apr -10 3.83 1,955 76 4.47 2,210 111 19- :z 1,964 81 4.44 .. � X2`10 '�,R� 20- Apr -10 �� 3.85 1,982 77 4.45 2,235 1,619 21- Apr -10 4.02 2,049 56 x.48 2,242 4 22- Apr -10 3.95 1,907 68 4.45 2,236 1,503 23- Apr -10 3.79 1,960 62 4.44 3, 4 .{ �:. 1,661 24- Apr -10 3.83 2,001 60 4.46 2,228 1,701 25 u .. 2,006 70 4.46 1,729 26- Apr -10 3.85 1,983 60 4.47 2,248 1,661 27- Apr -10 3.93 'k 60 4.4 : ` 2,236 1,657 28- Apr -10 3.97 2,025 60 4.44 2,266 1,666 :.2!�- Apr -10 3.95 1,986 66 ""4.48 2,255 z�3 30- Apr -10 3. 99 1,994 61 4.44 2,223 1,697 - May -10 .xt 3.96 2,001 57.E 4.45 1,69 2- May -10 4.01 1,992 58 4.48 2,198 1,647 3- May -10 3.79 1,881 „r 63 4.47' 2,19 `� 1,184: 4- May -10 3.85 1,866 66 4.78 2,228 1,014 5- May -10 3.93 x;964 58 447 > 2,187 6 6- May -10 3.97 1,882 55 4.68 2,097 1,542 7- May -10 3.83 1,894 70 4.49 4 8- May -10 3.87 1,895 64 4.49 2,187 1,563 ..: 0 .N , 1,942 j', 55 4.48; , 2,14 1 1,572 10- May -10 3.87 1,918 56 4.47 2,094 1,563 11- �71ay- 0� 3.79 1,852 65 4.45 r 2,162 1, 12- May -10 3.98 1,949 56 4.43 2,167 1,512 13 -May It} RR 3 0.. 1,985 59 4.53` 2,176 1,5 14- May -10 3.87 1,947 60 4.44 2,187 1,551 15- May -10 3.70; 63 4.42 7' 16- May -10 3.77 2,000 60 4.46 2,156 1,778 17- May -10 4.02 2,015` 54 4:49 2,160 � � , 5 18- May -10 3.88 2,013 56 4.46 2,178 1,708 19- May -10 ',.... 3.$9,:. 2,018 57 4.45 ' 2,1 x�w 1,7 20- May -10 3.50 1,972 75 4.39 2,259 1,581 21 -My. 1,926 79 4.44 2,196 161 22- May -10 3.83 1,923 67 4.45 2,151 1,543 23-�My -10 1,667 69 4.43 36 24- May -10 3.87 1,961 68 4.42 2,128 1,718 3.98 ., � 61 4.46 �� 2.144 1,726 26- May -10 3.85 1,972 71 4.45 2,125 1,786 27 -May40 3.81 1,996 65 '4.46 2,175 28- May -10 3.76 2,046 58 4.52 2,127 1,792 29 -Ma .. x.75 1,997 59 4.47 X20 1,588 30- May -10 3.65 1,967 61 4.42 2,143 1,588 31- May -10 '`` ��° X57 1,662 57 4 2,118 1- Jun -10 3.80 1,882 57 4.48 2,271 1,507 2- Jun -10 3.75 2,136 55 4,44 ' ` ` 1,806 3- Jun -10 3.02 2,016 59 4.40 2,781 1,709 4- Jun -10 4,08 7 1 11 1;9$8 56 4.49 2,22 ,E � X04 5- Jun -10 3.62 2,023 56 4.50 2,227 1,773 6- Jun -10 4.25 2,001 55 4 53 x` 2,219 1`13 7- Jun -10 4.15 1,987 56 4.53 2,223 1,763 8- Jun -10 392' °• , 1,980 60 4.48 38 9- Jun -10 4.10 1,997 56 4.46 2,198 1,733 10- Jun -1© w> 2,045 60 4.4$ ,;285 ",757• 11- Jun -10 2.66 2,167 70 4.53 2,419 1,770 12- Jun -10 4.01 1,999 61 4.46 ` ` 2,208 _ 1, 6 13- Jun -10 3.96 1,988 59 4.50 2,207 1,733 14- Jun -10 38.:' 1,938 6$ 4,50 1,616 15- Jun -10 3.84 1,964 78 4.57 2,218 1,741 16= lun -10 3.78 2,,001 82 4.52 ":,: 2,503 ` _ %.. f 17- Jun -10 3.81 1,945 82 4.54 2,425 1,569 18 tun -10 , r ..,. 3.89 1,954 62 %4.58 2;159 "x ,. -' 1,6G5 19- Jun -10 3.85 1,988 55 4.46 2,112 1,790 20-Jun-10 0 0 t;f?0 0' 21- Jun -10 4.15 1,961 54 4.44 2,048 1,864 ° - Jun -10 4.02 1,936 '56 4.44 2,. "� � 1,768 23- Jun -10 4.03 1,918 62 4.49 2,080 1,702 24 -J un -10 4:04' 1,945 58 4.49 . r 2,095 1 X702 25- Jun -10 3.97 1,950 63 4.55 2,113 1,738 - Jun -10 4.16 '1,979 52 4.47 � 2��2 IV 1,8 27- Jun -10 3.99 1,934 62 4.56 2,125 1,723 28- Jun -10 1,918 63 4,44 2,132 "`' 1,661 29- Jun -10 4.02 1,944 60 4.49 2,141 1,628 30- Jun -10 3.89 1,959 55 4.45. 2,152 „` A 1- Jul -10 4.19 1,992 54 4.49 2,133 1,857 3.92 M =a . 1,934 62 4.49 .tx�18$ 7 1,743 3- Jul -10 3.72 1,739 71 4.50 2,172 1,159 i 4- Jul-10 4.03 7.. * 0 1 2 56, 4.49 2,153 1, 5- Jul -10 3.98 2,006 61 4.45 2,147 1,875 .,7' 1,914 59 4.48 2 16 " �:. 1,:560 7- Jul -10 4.02 1,918 58 4.44 2,153 1,474 8'7u -10 ` x`89 67 x,1 41 9- Jul -10 3.74 2,027 78 4.40 2,325 1,682 10- Jul -10 4.14 2- 53 :; 4:d4�. : 2,162 11- Jul -10 4.00 2,052 59 4.48 2,188 1,871 _.,wu�... 3.91 2,025 61 4.47, 1,0 12 -Ju 1fl 13- Jul -10 4.02 _ 1,957 63 4.43 2,166 1,553 14- Jul -10 3.97 2;010, i � --" 66 4.44 2,1 1,749= 15- Jul -10 4.01 2,063 58 4.48 2,229 1,654 166- 1ul -10 4.09 2,088 53 4.43 17- Jul -10 4.00 2,094 62 4.43 2,198 2,006 18- Jul -10 4.09 2;068 57 2,184 19 -J u I -10 4.15 2,064 57 4.43 2,188 1,920 20- Jul -10 ` 3.84 2,002 64 4.44 2,18 21- Jul -10 3.92 1,930 69 4.45 2,191 1,661 22- Jul -10 3.86 2,019 65 4.40 2,260 ', >° ' 1,686 23- Jul -10 3.96 2,074 61 4.42 2,241 1,727 24- Jul -10 3.86 2,078. 62 4.40 7243 1,683 25- Jul -10 3.77 2,073 66 4.38 2,217 1,842 26- Jul -10 4.02 2,072 60 4.48 ;192 1 31 27- Jul -10 3.96 2,094 61 4.56 2,191 1,882 28- Jul -10 3.87 1;994 ` 64 , 4 , , V 2,179 . 29- Jul -10 4.08 2,088 57 4.49 2,181 1,918 30 -J u414 3.98'., 2,101 64 - 4.53 `' 2,18.., zPl 1.9 31- Jul -10 0.00 0 0 0.00 0 0 0 0 0.00 - { 0 2- Aug -10 4.04 2,066 65 4.49 2,166 1,900 3- Aug -10 4.57 `.:2z 52 2,141 1 A 4- Aug -10 3.99 2,023 55 4.51 2,146 1,864 7 `, -Aug -10 v t,..: 4.07 2,042 64' 4.49 2,140, ,875 6- Aug -10 0.00 0 0 0.00 0 0 7 -Aug 3.7 *.# . 1,996 79 4.48 8- Aug -10 3.95 2,033 59 4.55 2,141 24 9- Aug -10 4:80 56 5:79 x,14 1 x915 10- Aug -10 4.89 2,075 57 5.86 2,155 1,908 11- Aug -10 4.21 2,106 60 6 85 2,446 22 12- Aug -10 3.44 2,145 59 4.57 2,468 1,895 13- Aug -10 3.88 2,068 61 4.53 ? t;918 14- Aug -10 3.94 2,057 62 5.91 2,148 1,874 15- Aug -10 3.51 217 , .' 62 4.5¢� 175$ 16- Aug -10 2.96 2,267 67 4.52 2,377 2,010 s. 17- Aug -10 2.67 2;308 64 4 5th 2,423 2 2 18- Aug -10 3.22 2,236 66 4.58 2,435 1,944 , g -.10 3.49 1,719 58 6.13 M -6, 20- Aug -10 4.44 2,129 52 5.94 2,309 1,897 21- Aug -10 , ; 4. 2 50 5.98 ,u s n r `2,203 1,88 22- Aug -10 2.72 2,318 69 5.92 2,445 1,903 P -Aug-101 3.65 1,546 591 5.991 2,424 �, . 1 24- Aug -10 3.31 391 64 5.41 715 -4 25:Agg - 4.62 2,094 ... 54 6.15 ...n..:2,189 wt.u:.�,$ ,', 26- Aug -10 4.40 2,021 63 5.98 2,271 1,771 27- Aug -10 4.33 1,910 68 6 00 2,253 .., 28- Aug -10 4.29 1,996 71 5.97 2,250 1, 633 X29- Aug -10 4.17 2,022 69 5.99 s 30- Aug -10 3.38 2,079 67 5.97 2,260 1,835 3:53 2,296 70 5.27 x,303 -11 1- Sep -10 3.71 2,123 58 4.49 2,274 1,843 2' Y 2,190 5$ 4.53 2,299 044; 3- Sep -10 3.89 2,137 69 5.86 2,308 1,969 4- Sep -10' 4.20 2 2 : 54 2,321 �; 5 5- Sep -10 4.51 2,189 52 6.06 2,279 2,016 , . , O- Sep-10 4.70 2,215 52 6.04 2;289 = 0 7- Sep -10 3.96 2,088 72 5.96 2,366 1,835 &Sp -10; .. 3 7 .. 2,072 82 4.43; 1,824 9- Sep -10 4.04 2,07 79 6.01 2,311 17 10- Sep -10 3.87 Z 78 6.h9 2,365 11- Sep -10 3.95 2,0 9 72 5.98 2,334 1,728 $fi .. -Sep -10 3.81 2,0 4 81 4.53 r, 2,493 7$2 13- Sep -10 3.54 1,9 4 57 6.01 2,313 29 14- Sep -10 ` 3.60 2,1 4 65 6.13 2,45 ;kx.. 1,777 15- Sep -10 3.82 1,9 6 56 6.10 2,295 495 16 �. . . , ._ 42$ 2,0 9 69 6.12 �2s306 1,7 17- Sep -10 4.59 2,0 3 62 5.82 2,306 1,798 18- Sep -10 4.08 2 61 5 8"1 2,28$,0 19- Sep -10 4.55 2,1 9 54 5.81 2,299 1,770 M Sep -10 4.41 2,0 63 5.81 2,279 t� 1, 21- Sep -10 4.56 2,0 1 70 5.83 2,309 1,741 1,9 69 ` 5.81 2;320 1,601' 23- Sep -10 4.76 2,0 61 57 5.80 2,311 1,481 24- Sep -10 4.58 2;fl 2 57 6;g3 2,343 X33 25- Sep -10 4.57 2,0 2 66 5.83 2,341 1,481 t =, -Sep 1(. ., 4.94 2,2 2 :45 5.81 ``� 2,2 .�° 2, 27- Sep -10 4.35 1,7 0 69 5.84 2,310 1,122 28:3ep -10 4.36 1 t 63 0 507 29- Sep -10 4.13 2,0;1 60 5.81 2,292 18 30- Sep -10 4.54 2,1591 62 5;II1 2,30 K , X28 Attachment 2: Monthly Infection Totals and Waste Stream Summary Monthly Injection Totals Volume of,, Month Injected Fluid" July 2009 44110 August 2009 45714 September 2009 47113 October 2009 41574 November 2009 58046 December 2009 45466 January 2010 68548 February 2010 46577 March 2010 58679 April 2010 60877 May 2010 50033 June 2010 42592 July 2010 37541 August 2010 48233 September 2010 58541 Page 1 of 1 Attachment 3: Waste Stream Summary Physical, Chemical and Other Relevant Characteristics of the Injected Fluids Non Colid =Waste stituerNs r.;#Cow • Incidental non - hazardous wastes Wash water, seawater used generated by module operations & Waste characterization sampling Utility modules sump maintenance for drilling mud make-up, potable water chemical completed and verified not RCRA- fluids • Incidental equipment leaks additives. Process control is hazardous — Generator knowledge • Additives for Reverse Osmosis & potable used water systems strictly maintained Waste characterization sampling Glycol /heat exchange , Vehicles &eui Glycol (MEG, DEG, TEG, completed and verified not RCRA- media equipment (antifreeze) propylene) hazardous — Generator knowledge used • Fluids recovered from cleanup of non- Water, snow, gravel, with Waste characterization sampling Non - exempt spill completed and verified not RCRA- exempt spills hydrocarbon or chemical clean -up . Spill impacted gravel or snow products hazardous — Confirmation sample 08 -08 -10 Water, glycol, possible Waste characterization sampling Hydrotest fluid • Pressure test new or non - exempt process product residual in existing completed and verified not RCRA- (water or glycol only) lines, vessels lines, traces of chlorine or hazardous — Generator knowledge other biocide used Boiler blowdown • Rig or production facility boilers Water Not injected year to date, fluids used for drilling mud make -up water • Off spec product Products spilled, out -dated or no longer Varies — MSDS reviewed Generator knowledge used to verify acceptable for original purpose not RCRA- hazardous • Outdoor containment around fuel and Water, possible traces of Waste characterization sampling Contained snow / Y 9 completed and verified not RCRA- p e chemical storage tanks hydrocarbon or chemicals if P onded water hazardous — Generator knowledge Depressions on or between pads &roads there have been spills used g Motor oil Routine verification sampling Lubrication oil •Transmission fluid Hydrocarbons/water mixes conducted to confirm not RCRA- — Typically yp y hazardous T sent to • Hydraulic oils hydrocarbon or offsite recycle • Internal or external washdown of skids, modules Water, possible traces of Waste characterization sampling Non - exempt facility • Equipment cleaning (using non- hydrocarbon, chemicals, completed and verified not RCRA- wash water hazardous detergents or degreasers) detergent hazardous — Generator knowledge • Residues removed from RCRA -empty used containers Waste characterization sampling Incinerator ash • Trash and camp waste Particulates /RCRA metals completed and verified not RCRA- * Sewage sludge hazardous — Confirmation sample 08 -08 -10 Domestic • Camp wastewater treatment plant(s) and Water, soap residuals, human Generator knowledge used to verify wastewater/ sludge site enviro -vacs waste not RCRA Reverse osmosis • Saline concentrate from reverse osmosis Generator knowledge used to verify concentrate /seawater process for making potable water from Saline water not RCRA seawater Notes: 1. Similar wastes may be RCRA exempt, depending on waste - generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 United States Environmental Protection Agency F 7 Y I Region 10 % "' 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 e-mail: cutier.thor @epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. Pioneer - Oooguruk Unit ODSDW 01 -44 AK- 1I009 -A 207 -140 Injector MIT Type Test Type T to Class I T X IA Std. Annular Pressure Test (SAPT) Jan W2010 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) 3,500 Diesel 5,035' One Year Cycle Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. T START TIME: RECORDED PRESSURES (PSI) RESULT E 00:00 am/ pm PRE MITI INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING T INNER ANNULUS OUTER ANNULUS Z O 1 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: Initial MITIA as Class I well with ri (witness T.Syed), to 4,970 psi and thg to 5000 psi - 1/27/08. Last tested MITIA to 3,500 psi on 1/25109 (witness T.Syed). Total loss over 30 minutes - 102 psi OK. NOTE: Pressure must show stabilizing tendency: 1) Total pressure loss must be less than 10 % at end of 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Start MIT over if: 1) Total loss exceeds 10 % 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on -site decision per Inspector). 0 0 0 -- E -mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Talib SO, P.E./ Thor Cutler 1e.4.- O�rQ�C • • ,.. �► i• ♦ ��I s a � �� '• :� � '�' � � err ! ,� •. s �"" ' • �' +"�r'� +,• '� �� . �`•�►. �• - .- ..,�„ t mn►+ - I 1Nt1 �ttK� �. . _ - ,,,�� w • fi �� j !1�'� ` � � � '�� „�+1►�t�v.�►�� _ .�r...'► ' ,.tai` ��ri�i'�_ . ��le. .� . 11i��i;��/Ni�►1//, 'I' 'I IIIIIIII� I �II' i!I I IIII l J1911 ��c',h�l��!JIII��JI�J��P ��''' �IIIII_ I�u��IIiIIII +VIIIiI�VI1V�lll�'V�IIIW ~ ~ ~ ~ Page 1 of 1 Regg, James B (DOA) From: Norman, John K(DOA) ~ L ~I ~~~~~ Sent: Thursday, July 02, 2009 10:42 AM ~~ To: Regg, James B (DOA) Cc: Seamount, Dan T(DOA); Foerster, Catherine P(DOA); Colombie, Jody J(DOA) Subject: FW: PNR Annual UIC Report Attachments: PNR UIC Annual Report July 2008-June 2009 07-01-09.pdf Jim? From: Williams, Theresa [mailto:Theresa.Williams@pxd.com] Sent: Wednesday, July 01, 2009 8:46 PM To: Norman, John K(DOA); Regg, James B(DOA) Cc: Williams, Theresa Subject: PNR Annual UIC Report Commissioner Norman, Attached you'll find a copy of our annual UIC report for the disposal well at our Oooguruk pro ject and hard copies have been sent via US mail. I was wondering if you would consider changing the reporting period for future reports so they coincide with the annual reports we submit to the EPA and ADEC. Both of them cover the period from October lst of one year to September 30th of the next and the majority of the data is identical with that submitted to you. If you are agreeable we could submit another annual report for the period of Oct 2008 - Sep 2009 by October 31St in order to get this report in cycle with the others. Your consideration is appreciated. Please don't hesitate to contact me if you have any questions. Regards, M Theresa Williams Pioneer Natural Resources, Alaska Staff Operations Engineer (907) 343-2104 (907) 382-3596 cell Theresa.Williams anpxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 7/8/2009 ~$ ~ ~ ~~~~~~~~ PIONEER J~~.~~2~a~ NATURAL RESOURCES ALASKA ~i~~~~ _'~~ _~~ ~~~ ~~~~. ~~mmissi~r~ m r~w~?~sra ~ Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277-2700 Fax: (907) 343-2190 July 1, 2009 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2007-2008 Annual Performance Review for Oooguruk Unit DW-1 Dear Commissioner Norman: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW-1), in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) Disposal Injection Order No 31, Rule 6. T'his surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by July 1 of each year and include data sufficient to characterize the disposal operation: • Pressures and injection rates; • Fluid volumes injected; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW-1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, sunlmarized, and included in this report for dates from July 1, 2008 through June 30, 2009. DW-1 Iniection Pressures and Rates Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis as well as average and maximum injection rates. The averages were taken from one-minute readings during injection periods; additional raw data can be provided upon request. ~ • Oooguruk Development Project DW-1 2007-2008 Annual Performance Report Ju1y 1, 2009 Page 2 DW-1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. This attachment also includes a summary of physical, chemical, and other relevant characteristics of inject fluids. Assessment of Fracture Geometrv No additional assessment has been completed since the modeling done in June 2008 that supported a 6 bpm injection rate and 14 ppg. Description of Anomalous Injection Results No anomalous injection was noted during this reporting period. The pumps used with this well are used on other operations when not needed for injection, therefore these periods of use were removed from the data set. Calculated Zone of Influence for Injection Fluids No changes have been made since Pioneer submitted a model in June 2008 that supported the current injection rate of 6 bpm. The Zone of Influence is still considered to be sunilar to modeling conducted for this disposal operation. Other Attachment 3 is a graphical representation of the EPA-witnessed mechanical integrity test that was conducted on the inner annulus January 25, 2009. Attachment 4 is a graphical representation of pressures (injection, inner annular, and outer annular) for the reporting period. If you have any questions or require additional information, please contact Theresa Williams at (907) 343-2104 or theresa.williamsQpxd.com. Sincerely, . D. Hall Operations Manager - Alaska Enclosures: Attachment 1: DW-1 Performance Evaluation - Daily Injection Data Attachment 2: Monthly Injection Totals and Waste Stream Summary Attachment 3: MITIA Attachment 4: Pressures • Oooguruk DW-1 • Attachment 1: Daily Injection Data page 1 of 7 Average Average Maximum Maximum Minimum Injection Injection Average Injection Injection Injection Rate Pressure Temperature Rate Pressure Pressure Date (bbl/min) (psi) (°F) (bbl/min) (psi) (psi) ~~~ II ~~ ' ' ''i~l~ ~ii, 2.6 7 ~ ` ~f ~z ,''„ ~~i~l ~~~i~ ~~~~~ ,li, , ~ ,~"~, f ~'i :~ ,"~ ~ ~.~,~ 2-Ju1-08 3.0 1589.8 65.8 ~ 3.5 1766.3 1413.9 Ik I _ ., : ~r I v ~~ ; i 9f01~1 ~o „Lhl~ll ~~~. ~N}." S ~ -- ~YI ~ ~u~l~'I~~~' ~'d~i~ II I ~~~' ;~ - ~ 4-Ju1-08 ~ 3.1 -~ . 1526.4 62.8 , a .,.. - 3.5 . 1777.2 ~,.._.. . 1300.6 _ - _ _ . _ - , . .. 6-Ju1-08 1 08 1.1 3 1 1547.6 = 5 54.0 59 - _ 2.0 3 1670.6 528.6 ~ 4 - 8-Ju1-08 . 2.7 . 1546.0 . 62.4 .5 3.6 1848.5 1685.7 ~. 1366.1 ~ ~ ~ _ ~ . , ~, , ~~~~ t, s ,~. ., _ ~ ~ ~ ~~ ~ ~ ~° '; ^~'n"'~ ~ s ue. 4u ~ _~ ~ 10-Ju1-08 I 3.0 ~ 1384.1 I ~ti ~ 82.8 Ih °~ ~~ ~~ r ~ .~~ 3.5 1887.1 ~;; 1057.3 ~ ~~~i ~~ . ~ 12-Ju1~08 i ~ „, . ~~ 3.1 ~ ~. . - 1268.4 = ~ ~~ ~ ~~ ~~ ~i r ~I 85.1 e i~ ~'° ~ ~ ~,~ _ . T. 3.5 ~ ti1726.0 i~~ ,~ ~ ~ ~ - - F 1095~9~ = 14-Ju1-08 3.~0 1602.4 ~ ~ ~ u 55.6 3.5 ~ 1719.~3 1247.7 ~ ~ Q~ ` 16-Ju1-08 3.0 1529.6 ~ ~ 59.5 ~ 3.5 , 1736.9 ~ E 348.2 ~ ^~ q - 18-Ju1-08 2.9 p, I ~iil i ~. ~„: '~ '~ ~ 1664.6~ ~~.'' I . _. 53.5 Sr ~, ; rn.~ 3.5 ~ ti,~~~ i ',;~~,. 1771.3 n ~~ ; ` 1379.5 ~~~~ I ,~~ I~~ '~~ ~ aV ~ "~~ ' ~~ ~ ,. ~~b ~ ~ ~ ~ ~ _ ~r~~~~~ ~ _ 20-Ju1-08 ~ ~ 3.0 1 631.9 - 55.9 , t~ ~ - ~3.6 1783.9 - 1138.7 _ , - ~: -= 22-Ju1-08 ;;. ~8 .,. .. .,. 1.1 3 0 ~ _ ~ - 1426.6 - ~, , 54.5 .0 ~ _ 1606.9 ' . ~' 442.2 - - 24-Ju1-08 . 1.2 1443.0 58. 56.3 , 2.0 1825.9 1624.5 = .7 ~ 760.2 ;`° _ 26-Ju1-08 „~ . ;~ _,T_ ,~ 3.0 - 615.1 ~-~ T W , ~~.. ., , 55.1 = .6 - ~ : TE~._... 1752.0 9.2 61.7 ~ i u 28-Jul -08 ~ 2.8 ~ k~ ~ 1608.5 ~_ ~ 53.7 = N 3.5 1757.9 ,' 422.9 30-Ju1-08 2.9 1648.9 =- 53.8 - _ 3.6 1757.9 1231.8 1-Aug-08 3.0 1654.8 56.4 3.7 1783.1 = 9150.4 ~ ~ ~ 3-Au -08 2.8 1699.1 ~ 56.5 3.5 2075.9 ~ ~; ~ ~ 73.8 - - 5-Aug-08 :~~~ ~' 6°~ 3.0 1531.8 67.7 3.5 1914.0 1197.4 _ y` 7-Aug-08 3.1 1409.0 72.8 3.5 1768.0 l 266.0 9-Aug-08 ~ 3.1 1481.0 64.3 3.5 1772.2 1225.1 11-Aug-08 ~ 2.8 ~ 3 1 585.9 1 57.7 3.5 1805.7 7.6 13-Aug-08 , ,.. . ? w . . 2.8 :- ~ 1611.6 . ~ 54.8 :~ - 3.5 1742.0 0.0 115-Au -08 3.2 ~_ _ , 9 - 1609.6 ~ 66.9 3.7 1853.6 1417.2 17-Aug-08 3.0 1730.9 69.1 3.5 2143.9 1497.0 19-Aug-08 2.9 1570.9 75.4 3.7 1774.7 934.8 21-Aug-08 - 1 3.1 1646.5 ~ ~ 58.8 3.6 ~~- 1784.8 1455.8 2 3-Aug-08 3.0 , ~~~ - 1664.4 ~~~I 53.9 3.6 1835.1 p266.0 • Oooguruk DW-1 • Attachment 1: Daily Injection Data page 2 of 7 Average Average . Maximum Maximum Minimum Injection Injection Average Injection Injection Injection Rate Pressure Temperature Rate Pressure Pressure Date 24-Au = (bbl/min) '3 0 (psi) ~8 2 (°F) 50 8 (bbl/min) 3 ~ (psi) - ~ -- (psi) - . . = . .- == -- 25-Aug-08 2.9 1654.5 56.8 3.5 1835.1 1543.9 2~ }~ =s ~~ 0 54 5 - : ~ . - ~. ~{ 27-Aug-08 _- ~~ 2.7 1656.0 ~ 55.2 3 5 1762.1 1533.0 - , _ . n .8 59.6 - . _ 29-Aug-08 ~~ ~ 2.6 2 8 ~ 1666.4 1~~ 63.6 67 4 : 3 5 - ._ 1813.3 ~ _ 456.5 - ~, 31-Aug-08 . 3.0 1509.6 . 69.6 3 4.0 ..•~~_~._ 1767.1 82.2 .r - ~ _- [ ~ ~ i~ i ~I~~ ~ .' - ~.~ ~ ' I i~• . ~~ a~, I ~n n i il~. i iw i I I~ ~ _ ~a ~.„, .. ~" _ . . 2-Sep-08 2.7 1605A , ~ 56.9 3.6 .:1829.2 y 443.0 IIIhEI ~_ ~ _ ~ dl ~ r r~ I~~I~~II{o I: ~~ i. II .flyi S~ MI . I' IIIIoE~t~.:~~llli i CII il I~ Illlpii II~~~~1I.~1', i p~=~ ~ II ^v~ ~ T ,3....~. ~ 4-Sep -08 3.0 1591.4 62.9 3.6 1777.2 187.1 !,~4I '=~ ' d~r ~ =`~ ~ ' " ,~ , ~U ,,+, ~ ~ '~` c9, ! ~;i~~l d ` ~~,r;~.' ~ p~ ~,i I~~~i~~ ~~ - ~~~ ~I ~~ i' ~~,ii 'a'~u'„q, i ' 6-Sep-08 ,~, ^ I 2.9 ~ s 1706.3 ,p f ~~ ~1 ~ 49.0 ~ ' i ~'~ ~ 3.5 1814.1 - ~ ~ 1508.7 '~~ ~ : 8-Se -08 _ - _- ~ ~~2.'7 ~ _~ ~ a ~~ 1506.5 r,~ ~ ~ ' a ~~ ~~ ~~ ~,~.~~~ 69.4 ~~~~~~~~~~~, ,,. = 4.1 ~~~~ P~ ~~ 1844.3 ` : _ ~ ~~ 158.6 ~ 0-Sep-08 -- ~ .1 II ~~ . . :~~ .. II 1388.2 ~: _ cE ~, , , I~ 74.1 .1 r , ~ 1804.9 ~ ---- 1073.2 _ ~ ,~; n 12-Sep-08 3.0 1655.8 51.2 3.5 1772.2 595.8 , 14-Sep-08 ~ 2.8 - . 1326.9 8 ~ . 72.6 6 7 - - 4.1 ` ~;~~ ~ .:.. ,..~ 1804.1 - -_~ _ 930.6 - 16-Sep-08 3.0 . 1521.9 6. 57.0 3.5 - - 1908.1 1043.0 18-Sep-08 _ 2.9 d ,~ 1567.7 ~ 57,9 _ 3.6 _- 1790.6 = 1187.3 - 20-Sep-08 ~ 2.6 ~ 1658.9 ~ a ~m : 57.6 =- _ 3.6 :~~:; ~ 2157.3 1348.4 22-Sep-08 ~~: - 3.0 ~ ~ . 1648.8 '? 49.5 3.6 ~ e 1744.5 r 1369.4 24-Sep-08 3.0 ~~;~ ; 1663.0 49.2 3.5 ~ 1778.9 - 897.0 ~ _ ~ .,~~,u~~ ' '~: ~'' ~~I~! ~~''~ ~~~.~, ~i 26-Sep-08 2.7 1671.2 50.5 3.5 1785.6 1357.7 ~,, ~~ ~ ` J ;~l ; ~ a ~ : + i ~ ~~ 28-Sep-08 3.1 1519.3 55.4 3.6 1797.3 ~' 1004.4 -_ 30-Sep-08 3.0 ' ~' ° 1610.2 48.5 3.5 ,4 1794.0 - ~~. ,~.8 920.5 2-Oct-08 _ ~ , ~ 1.7 640.4 73.8 ~ 3.5 - 1837.6 - 70.5 4-Oct-08 OA 0.0 0 0 ,. 0.0 0.0 0.0 0.0 6-Oct-08 3.1 . 1593.6 60.1 3.6 1820.8 500.1 8-Oct-08 3.1 1555.4 j 56.6 3.5 1780.6 1134.5 10-Oct-08 3.0 a 1644.7 ~.. 54.0 ,.. '~~ ~ "'~ ' ~ - 3.6 1823.4 1250.3 12-Oct-08 _ . 2.9 1710.7 ~ ~ ~ ~ 47.4 ~, 1 3.5 1841.8 1257.0 - - ~ 14-Oct-08 3.0 ~ ~ ~ 1662.3 ~ I 52 .4 - ~~ 3.6 ' ~ - ~ 1855.2 ~ " ^ 381.0 ~ ~~ y: a 16-Oct-08 ~ ~ ~1 ~~ 2.9 ~ ~ 1~549 3 ~ '` 61.0 ~~ ~ 3.6 ° - - ~ 1908.9 688.1 ~ • Oooguruk DW-1 0 Attachment 1: Daily Injection Data page 3 of 7 Date Average Injection Rate (bbl/min) Average Injection Pressure (psi) Average Temperature (OF) Maximum Injection Rate (bbl/min) Maximum Injection Pressure (psi) Minimum Injection Pressure (psi) -1 7-Oct-08 3.0 61.2 20.7 1387.9 18-Oct-08 3.1 1480.2 62.9 3.6 1836.8 1136.1 19-Oct-Q8 3.1 20.51 1663.5 57.9 3.6 1852.7 1477.7 20-Oct-08 54.5 3.6 2497.2 51.2 22-Oct-08 3.0 1749.4 55.1 50.2 R 3.7 1857.8 1377.0 23-Oct-08 3.0 1726.8 54.7 3.6 WJ,9 1896.4 17ff -2 1412.2 24-Oct-08 3.1 1635.3 60.8 25-Oct-08 2.9 1749.4 52.1, 3.6 --7W.9 1524.6 26-Oct-08 2.8 1805.1 51.21 4.1 1917.3 1577.5 27-Oct-08 3.0 1733.6 6 10,6 28-Oct-08 3.1 1600.4 63.7 3.5 1939.2 1324.9 29-Oct-08 3.11667.1 .8 3 z 1917.3 30-Oct-08 3.1 1657.7 57.4 3.6 1926.6 1434.0 31 -Oct-08 3.1 1800.8 52.0 .5 M197.2 "11596.8 1 -Nov-08 2.9 1798.5 48.5 3.5 1908.1 360.0 2-Nov-08 1.0 1737.5 533 2.1 1807.4 1460.0 3-Nov-08 3.0 1796.5 48.1 3.5 1882.9 1441.6 4-Nov-08, 3.2 1829.9 54.9 3.6 1904.8 235.8 Nov-08 3.0 1796.9 55.7 3.6 1930.8 1547.3 2.9 1746.5 61.5 3.5 1962.6 1502.0 3.0 1725.1 60.2 3.7 2049.1 1459.2 3.1 -1 54.0 3.5, 2010.5 1313.2 9-Nov-08 3.1 1713.7 60.4 3.6 2023.1 1284.71 1 O-Nov-08 3.0 1774-77111 �-, 8 3.5 1984.5 1471.8 11 -Nov-08 3.0 1841.4 50.3 3.6 2024.7 1419.8 12-Nov-08 3.1 1773.5 3.6 2008.0 1427.3' 13-Nov-081 3.1 1867.6 52.1 3.6 2032.3 1543.9 14-Nov-08 3.1 1836.7 53.2 3.6 2028.1 1208.3, 15-Nov-08 3.1 1899.7 47.1 3.5 2026.4 843.31 16-Nov-08 3.2 1506.2 65.5 3,6 3396.7 107.41 17-Nov-08 3.2 1851.5 54.3 3.5 2023.1 1688.3 18-Nov-08 3.1 1829.4 55.7 3.5 200 19-Nov-08 3.1 1875.2 50.1 3.7 2014.7 1625.3 20-Nov-08 2.8 1663.5 52.1 3.5 213- 21-Nov-08 1.0 191.3 60.5 1.0 191.3 191. 22-Nov-081 23-Nov-08 2.4 3.2 1332.9 1759.8 63.8 62.1 3.6 4.5 20MA 1947.5 1477.7 24-Nov-08 3.2 1750.4 66.2 3.6 1947.5 w3f 25-Nov-08 3.2 1829.9 50.4 4.5 1925.7 1596.0 26-Nov-08 3.3 1727.2 66.5 4.5 1925.7 1477,7 27-Nov-081 3.0 1796.1 49.0 3.5 1899.7 742.6 28-Nov-08 3.1 1718.3 63.3 3.6 1950.9 1408.8 29-Nov-08 3.2 1728.8 53.1 3.6 1903.1 1354.3 30-Nov-08 3.2 1550.0 62.4 3.6 1974.4 970.8 1 -Dec-08 3.1 1757.9 45.4 3.6 1849.4 1580.9 -2-Dec-08 3.1 1768.6 47.5 3.5 1908:9 1529.7 -3-Dec-08 0.7 501.7 59.5 2.1 1810.8 189.6 -4-Dec-08 3.1 1817.8 60.3 3.6 1916.5 1552.3 5-Dec-08 3.1 1745.1 62.2 3.6 1902.2 1574.1 -6-Dec-08 3.1 1741.2 62.9 3.8 1901.4 7-Dec-08 3.2 1742.2, 67.2 3,6 1949.2 1491.1 1 9-Dec-08 3.3 1709.8 1 65.5 3.7 2011.3 1681.51 73.4, 4.5, 1998.7 1390.4 page 4 of 7 . Oooguruk DW-1 • Attachment 1: Daily Injection Data page 5 of 7 . Oooguruk DW-1 • Attachment 1: Daily Injection Data • Oooguruk DW-1 0 Attachment 1: Daily Injection Data page 6 of 7 Date Average Injection Rate (bbl/min) Average Injection Pressure (psi) Average Temperature (OF) Maximum Injection Rate (bbl/min) Maximum Injection Pressure (psi) Minimum Injection Pressure (psi) 28-Mar-09 3.9 62.4 2043.2 1218.4 29-Mar-09 3.7 1572.5 73.0 4.5 2013.0 117.5 30-Mar-09 3.8 1714.7 68.6 2039.0 332.3 31-Mar-09 3.8 1707.4 68.0 4.5 2024.7 18.5 1-A r-09 u 0.0 U 0.0 0.0 0.0 2-Apr-09 3.7 1731.6 59.9 4.5 2065.0 1277.1 3-Apr-09 3.5 1624.5 70.4 1292.2 4-Apr-09 3.6 1775.9 54.9 4.2 2056.6 1366.1 5-Apr-09 3.6 1814.6 56.7 4.1 2105.3 1514.6' 6-Apr-09 0.0 0.0 0.0 0.0 0.0 0.0 7-Apr-09 3.8 1679.4 71.7 4`.5 2143.9 412.0 8-Apr-09 3.9 1867.6 48.8 4.5 1950.9 1661.4 9-Apr-09 3.6 1693 0 55.7 4.5 2070.1 1204.9 10-Apr-09 3.6 1554.6 77.2 4.5 2023.9 855.9 11-Apr-09 3.01 1891.2 43.1 4.1 2008.8 1783.1 12-Apr-09 3.5 1716.8 68.3 4.5 2035.7 1316.5 13-Apr-09 3.6 1774.1 60.4 4.5 - 2066.7 1371.1 14-Apr-09 3.7 1540.9 72.7 4.1 1854.4 1361.0 15-Apr-09 3.5 1665.8 64.1 4.3 2030.6 1461.7 16-Apr-09 3.4 1630.8 63.7 4.5 1989.5 1276.3 17-A r-09 0.0 0.0 0.0 0.0 0.0 0.0 18-Apr-09 3.7 1732.7 64.3 4.5 2081.0 1439.9 19-Apr-09 3.7 1810.5 53.8 4.6 2053.3 1479.3 20-Apr-09 3.9 1656.3 68.3 4.7 2062.5 1237.7 21-A r-09 3.6 1724.1 60.1 4,6 2017.2 1216.7 22-Apr-09 3.9 1857.9 52.7 4.5 1993.7 1498.6 23-Apr-09 3.8 1584.1 57.8 4.6 2013.0 1439.1' 24-Apr-09 3.8 1868.6 48.8 4.5 1981.1 1510.4 25-A r=09 3.6 1833.7 61.5 4.5 2173.3 1439A 26-Apr-09 3.9 1859.7 48.7 4.5 1953.4 1512.1 27-A r-09 3.9 1835.4 `' 52.31 4.5 1534.7 28-A r-09 3.9 1838.0 54.91 4.5 2015.5 1464.2 30-Apr-09 3.8 1856.1 56.0 --- - 4.5 = 2362.9 902.0 53.7 1-Ma -09. 3:5 59.7 - IME 1296.4 2-May-09 3.8 1847.1 51.5 4.5 1941.7 1480.2 3-Ma -09 16 1828.0 55.8 - 4.5 1568.3 47.8 4-May-09 3.8 1828.6 56.2 4.5 2027.3 5-Ma -09 3.8 1807.5 54.5 4 �W 1470.9 6-May-09 4.1 1808.6 54.4 4.5 1990.3 1443.2 7-Ma -09 4.0 1878.7 43.8 4: 8-May-09 3.7 1857.1 56.2 4.5 2048.2 1561.6 9-May-09 3.9 1890.5 46.7 4.5 10-May-09 3.6 1886.7 54.0 4.5 2077.6 1688.3 11 -May-091 4.0 1897.0 46.2 4.5 2019.7 1643.8 12-May-09 3.7 1838.6 61.2 4.5 2119.6 1576.7 13-Ma -09 3.1 1977.9 59.1 4.5 2310.0 1662.3 14-May-09 3.5 1860.9 53.7 4.5 2039.8 1682.4 15-Ma -09 3.7 1928.3 47.7 4.5 2112.0 1652.2 16-May-09 4.0 1934.7 46.6 4.5 2079.3 1556.5 77Ma -09 3.7 1894.2 52.0 4.5 2036.5 1579,2 18-May-09 3.7 1968.6 56.0 4.5 2091.9 1713.4 a -09 3.5 1915.01 56.8 4Z 2065.0 1606.0 20-May-09 3.9 1942.21 53.2 4.5 2162.4 1692.5 •Oooguruk DW-1 0 Attachment 1: Daily Injection Data Date Average Injection Rate (bbl/min) Average Injection Pressure (psi) Average Temperature (OF) Maximum Injection Rate (bbl/min) Maximum Injection Pressure (psi) Minimum Injection Pressure (psi) AHMED mluipx�, .1 49.5 .1 1711.8 22-May-09 3.9 1964.2 58.1 4.5 2128.0 1728.5 24-May-09 4.0 1894.7 51.2 52.7 4.5 4.5 1988 2062.5 1684.9 25-May-09, MIM40.5 59.2 4.5 2106 1 1 �Jjjll May-May 26-May-091 3.4 1895.9 62.6 4.5 2134.7 1664.8 27-Ma -09 M a -'9 m�=A 68.9 4.6 2249.6 M _ 28-May-09 8 M Y-09 3.8 1910.6 55.8 4.6 2081.0 1712.6 29_May-May 2.6-- -1381.2 65.9 4.6 2068.4 422.9 n M. nq 1 3 -May- 3.9 1877.4 53.3 4.6 2068.4 1559.9 31-May-09, 1-Jun-09 3.7 3.7 1810.9 1843.7 60.0 64.6 4.5 4.5 2061,4�.3 2063.3 1584.2 2-Jun-09 18 1889.8 69.0 4.5 2072.6 1 3-Jun-09 3.8 1902.1 58.7 4.5 2136.3 417.0 4-Jun-09 3.4 1824.0 58.0 4.5 2013.8'-- 15 5-Jun-09. 3.5 1826.8 58.1 4.5 2051.6 1603.5 6-Jun-09 3.6 1786,6 63.5 4.5 2028.9 14513, 7-Jun-09 3.6 1851.2 63.7 4.5 2004.6 1608.6 8-Jun-09 3.8 1843.5 52.7 4.5 2004.6 1661.4 9-Jun-09 3.6 1827.3 50.3 4.5 1983.6 1663.9 JoibL709 3.8 1842.1 53.7 4.5 2022.2 1616.9 -11 -Jun-09 1.0 1670.0 62.6 1.9 1804.9 480.8. -12-Jun-09 3.9 1856.7 56.5 4.5 2009.6 1591.8 13-Jun-09 4.0 1852.4 51.1 4.5 1996.2 1689.9 14-Jun-09 1.8 1690.8 57.2 2.3 1768.8 1581.7 15-Jun-09 0.0 0.0 0.0 0.0 0.0 0.0 16-Jun-09 4.1 1831.9 54.2 4.5 2008.0 1320.7 17-Jun-09 3.4 1825.6 51.9 4.5 2051.2 1606.91 18-Jun-09 3.7 1852.2 61.7 4.5 2253.0 1680.7 19-Jun-09 3.4 1931.7 71.3 4.4 2256.3 1829.2 20-Jun-09 0.0 0.0 0.0 0.0 0.0 0.0 21-Jun-09 4.0 1816.2 65.7 4.5 1965.2 1616.1 22-Jun-09 4.0 1823.8 51.0 4.5 1979-A 1591.8 23-Jun-09 3.9 1865.7 64.9 4.6 2004.6 1580.9 24-Jun-09 3.9 1872.0 57.6 4.5--- 1976.9 1710.9 25-Jun-09 3.9 1816.9 54.9 4.5 1962.6 1640.4 26-Jun-09 27-Jun-09 3.8 3.8 1804.8 1845.1 64.7 64.5 4.5 2024.7 1659.7 28-Jun-09 3.9 1798.1 63.7 AA 0_ 7 29-Jun-09 3.7 1864.01 64.4, 4.5 2004.6 1664.8 3-0-Jun-09, 3.8 1825.31 63.81 -TIF-7 _ page 7 of 7 hment 2: as~Stream Summa Physical, Chemical and Other Relevant Characteristics of the Injected Fluids ,_~ - i,~~" ~, ~ hll~ m x ~M~ ~uM' ~ ~'~"' ~ ~I) $~~_ " I~ ~ ~IU~I) " ~~) ~~') F w~~) ~ ~ ~~ ~~ - ~ ~r' (~' '~) ~~~n - ~ -~- k~'j~ =io - = Pr e s - tk ~ > ~ ~ - - -3i~s • Incidental non-hazardous wastes generated Wash water, seawater used for Utility modules sump by module operations & maintenance drilling mud make-up, potable U1-Utility module sump - Sampled on fluids • Incidental equipment leaks water chemical additives. 10/22/08 -Verified not RCRA-hazardous • Additives for Reverse Osmosis & potable Process control is strictly water systems maintained Glycol/heat exchange di . Vehicles & equipment (antifreeze) Glycol (MEG, DEG, TEG, Not injected year to date me a propylene) Non-exempt spill clean- ' Fluids recovered from cleanup of non- Water, snow, gravel, with Spot clean-up snow/gravel - Sampled on uP exempt spills ' hydrocarbon or chemical 10/22/08 and 5/15/09 - Verified not RCRA- • Spill impacted gravel or snow products hazardous Hydrotest fluid . Pressure test new or non-exempt process Water, glycol, possible product Hydrotest fluids - Sampled on 1/16/09, (water or glycol only) lines, vessels residual in existing lines, traces 2/21/09, and 3/20/09 - Verified not RCRA- of chlorine or other biocide hazardous Boiler blowdown . Rig or production facility boilers Water Not injected year to date, fluids used for drilling mud make-up water Off spec product • Products spilled, out-dated or no longer acceptable for original purpose Varies - MSDS reviewed Not injected year to date Contained snow/ • Outdoor containment around fuel and Water, possible traces of Secondary containment water - Sampled ponded water chemical storage tanks hydrocarbon or chemicals if on 8/21/08- Verified not RCRA-hazardous • Depressions on or between pads & roads there have been spills • Motor oil Lubrication oils - Sampled on 2/21/09 and Lubrication oil . Transmission fluid Hydrocarbons/water mixes- 3/21/09 - Verified not RCRA-hazardous, • Hydraulic oils typically sent to hydrocarbon recycle • Internal or external washdown of skids, Non-exempt facility modules • Equipment cleaning (using non-hazardous Water, possible traces of wash water detergents or degreasers) hydrocarbon, chemicals, Not Injected year to date • Residues removed from RCRA-empty detergent containers Incinerator ash • Trash and camp waste Particulates/RCRA metals Incinerator Ash - Sampled on 1/16/09 and • Sewage sludge 1/27I09 - Verified not RCRA-hazardous Domestic wastewater/ . Camp wastewater treatment plant(s) and Water, soap residuals, human Sewage Sludge - Generator Knowledge - sludge site enviro-vacs waste non hazardous Reverse osmosis • Saline concentrate from reverse osmosis Seawater Concentrate - Generator concentrate/seawater Process for making potable water from Saline water Knowledge - non-hazardous seawater Notes: 1. Similar wastes may be RCRA exempt, depending on waste-generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 Monthly Injection Totals ~~ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Pioneer Natural Resources Oooguruk ODSDW01-44 01 /25/09 Rauchenstein William Talib Syed - EPA • Packer Depth Pretest Initial 15 Min. 30 Min. Well ODSDW01 T pe In~. I TVD 5,035' Tubin 1,550 1,530 1,500 1,500 Interval O P.T.D. 2071400 T pe test P Test psi 3500 Casin 117 3,503 3,416 3,401 P/F P Notes: OA 0 360 360 360 Well T pe In~. ND Tubin Interva P.T.D. T pe test Test psi Casin P/F Notes: OA Well T pe In~. ND Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well T pe In~. TVD Tubin Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well T pe Inj. TVD Tubin Interval P.T.D. T pe tes Test psi Casin P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 EPA MITIA ODSDW01-44 1-25-09.x1s (1f~5f200~ 1:15:~,~ Ph1,~ 3517 p~i 400 (1JZ5J2009 2:34:33 RM) 3341 p,i ODSDW1-44 MIT IA Jan 25, 2009 -1Z6 psi ~0 da~a, 01:19:1d',~ ~ ~ 1:00 1~'25~'ZQ04 14Z.168.124.51:PI_~1001 [Cy~lic~ 0 PM 1,~'`~5;'2009 1~'z5~'2009 1j25~~'2004 1~t25,F2QQ9 1;'25,l2004 ODSDW1-44 Pressures July 1, 2008 - June 30, 2009 2500 2250 2000 1750 -- 1500 .N a m ~ 1250 ~ y C1 L a 1000 750 500 250 0 1-Ju1-08 Date ~ ~ ~ INJECTION OA - IA 20-Aug-08 9-Oct-08 28-Nov-08 17-Jan-09 8-Mar-09 27-Apr-09 16-Jun-09 ~7 • June 24, 2008 PIONEER NATURAL RESOURCES ALASKA, INC. James Regg Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Subject: Application for Amendment of Disposal Injection Order No. 31 Oooguruk Unit Developrnent Project Dear Mr. Regg: Disposal Injection Order (DIO) Number 31 authorizes operation of a Class II disposal well at the Oooguruk Development Project. As you know, this well began operation in February 2008. Rule 3 of the order limits injection rates to 4 barrels per minute (bpm). Pioneer Natural Resources Alaska, Inc. (Pioneer) would like to have the ability to inject at a higher rate to allow more efficient disposal of clear fluids and is requesting that you amend the order to increase the injection rate limit to 6 bpm. In support of this request we have supplemented the previous slurry injection model with new input parameters reflecting a higher injection rate and fluid density. Although we dori t intend to inject slurry at the higher rate, based on our discussion with you, we have modeled an increase in both rate and density to simplify the DIO amendment and future compliance. The simulation report (attached) shows that predicted fractures will remain confined to the Torok injection zone. The original simulation at 4 bpm and 10.1 pounds per gallon (ppg) predicted fracture half-lengths between 570 and 980 feet with heights of 140 to 230 feet. The new model runs at 6 bpm and 14 ppg are only modestly different in length and height from the earlier projections (approximately 790 and 270 feet, respectively). The main effect is to increase fracture width. The well performance to date supports the predictions of the model used for the slurry simulation reports. As evidenced by the attached performance curves, injection pressures have been in the range expected and do not appear to be sensitive to changes in injection rate or fluid density. 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277-2700 Application for DIO Amendment June 24, 2008 Page 2 As the simulation and performance data show that the injection rate can be increased while maintaining confinement, Pioneer requests that DIO No. 31 be amended to allow an injection rate of 6 bpm. If you have any questions or require additional information, please contact John Hellen at 907/343-2102. Sincerely, . "Joey" Hall Operations Manager -Alaska Enclosure: Simulation of Slurry Injection Report Well Performance Curves • • Simulation of Slurry Injection: Ooorguk Beaufort Sea Offshore Drilling Island Injection into Torok Sand [6 bpm and 12.5/14 ppg simulations] Prepared for: PIONEER NATURAL RESOURCES ALASKA, INC. 700 G Street, Suite 600 Anchorage, Alaska 99501 Prepared by: Energy &Geoscience Institute University of Utah June 2008 Energy &Geoscience Institute ~' Pioneer Natural Resource~ska, Inc. ~ Page 2 Oooguruk Beaufort Sea Offshore Drillin Island - Infection into Torok Sand (6 BPM, 12.5 and 14 PPG) TABLE OF CONTENTS I. Background .............................................................................................3 II. Matrix of Simulations ............................................................................. 3 III. Results ........................................... ................................................ 3 Appendix A (Results) ...................................................................................... 7 Energy & Geoscience Institute EG~ Pioneer Natural ResourcesAl"aska, Inc. ~ Page 3 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) I. I. BACKGROUND Pioneer Natural Resources is considering injecting cuttings slurry into a dedicated disposal well (ODSDW 1-44 (Disposal Well) in the Oooguruk Beaufort Sea Offshore development drilling island (Oooguruk Drill Site (ODS)). Hydraulic fracturing simulations were carried out using commercial and proven software (MFracT"') to assess the evolution of fractures associated with injection into this well. This summarizes simulation with 12.5 ppg and 14.0 ppg slurry at an injection rate of 6 BPM to satisfy a request from the State Oil and Gas Commission. These runs supplement simulations provided under separate cover in January 2007. II. MATRIX OF SIMULATIONS The variables adopted in the simulations were: • Four completion schemes. The four situations considered were as follows. 1. Injection into the entire Torok interval (open to injection from N5009.5 to N5269 ft through the perforations indicated in 2) to 4) below. 2. Injection into the Lower Torok sand (barefoot 5164.5-5269 ft) 3. Injection into the Upper Torok sand (perforated 5009.5-5105.5 ft) 4. Injection into the intermediate shale (5105.5 - 5154.5 ft). Two fluids were used in the simulations. These were 12.5 ppg slurry and 14 ppg slurries. Power law rheologies for these fluids were inferred and these are shown in Table 1. Table 1. Fluid Rheology Fluid n' K' (Ibf-s"~/ftZ) Weight (ppg) Specific Gravity Seawater/PW (base fluid) 1.0 1.313 x 10-5 8.66 1.04 9.5 ppg slurry 0.7 1.022 x 10-3 9.5 1.14 10.1 ppg slurry 0.7 7.156 x 10-3 10.1 1.21 12.5 ppg slurry 0.5 0.05 12.5 1.50 14 ppg slurry 0.5 0.068 14.0 1.68 • Two schedules were adopted for assessing. slurry injection. Various parametric simulations were run and key results are reported for the following scenarios. 1. 1000 bbls of 12.5 and 14 ppg slurry with spearhead and flush at 6 BPM. 2. 2500 bbls of 12.5 and 14 ppg slurry with spearhead and flush at 6 BPM. III. RESULTS Results of the fracturing simulations are summarized in Table 2. Figures for the various cases are provided in Appendix A. Based on the results, the anticipated dimensions for a batch injection are shown in Table 3. Energy & Geoscience Institute ~' Pioneer Natural Resources Alaska, Inc. Page 4 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Table 2. Summary of Fracture Dimensions at the End of Injection Case Completion) ZoneZ Rate (BPM) Injection Fluid Total Volume3 bbl ( ) Fracture Half- a Length (ft) Upper Heights (ft) Lower Height6 (ft) Maximum Wellbore Width (inches)' EO]$ Net Pressure (psi) 5a All 6 12.5 ppg slurry 1,000 Upper 315 96 41 0.19 200 Shale 342 126 47 0.21 153 Lower 492 65 76 0.29 280 5b Lower Lower 6 12.5 ppg slurry 1,000 679 117 78 0.39 293 5c Upper Upper 6 12.5 ppg slurry 1,000 583 108 103 0.37 250 5d Shale Shale 6 12.5 ppg slurry 1,000 602 134 52 0.34 213 5e All 6 12.5 ppg slurry 2,500 Upper 396 98 45 0.21 209 Lower 434 128 67 0.25 157 Shale 754 113 77 0.36 284 5f Lower Lower 6 12.5 ppg slurry 2,500 908 202 73 0.400 248 5g Upper Upper 6 12.5 ppg slurry 2,500 786 108 180 0.39 209 • 1 This designates which zone is open. The upper zone would be perforated. The Lower Sand will tentatively be barefoot. Perforations are also potentially open in the shale (above the shoe and below the perforations in the Upper Sand). • z Designates zone where fracture growth occurs. s Excluding displacement volume (spearhead and flush). a Fracture half-length is the length from the wellbore to the tip of one wing of an assumed symmetrical fracture (i.e., the modeling presumes that two identical fracture wings grow diagonally away from the wellbore in the direction of the maximum horizontal principal stress. s Designates the vertical upwards growth at the wellbore from the center of the specified zone. e Designates the vertical downwards growth at the wellbore from the center of the specified zone. ' Maximum wellbore width is the maximum fracture width at any. position along the wellbore. $ EOJ (end of job) implies after flush, at shut-in. Net pressure is the difference between the sandface injection pressure and the in-situ stress at the mid-depth of the completed zone. Energy & Geoscience Institute ~' Pioneer Natural Resource~aska, Inc. • Page 6 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Table 3. Average Fracture Dimensions (vary according to how the well is completed) Scenario Expected Volume Maximum Volume 1,000 bbl of Slurry 2500 bbl of Slurry 12.5 ppg at 6 BPM Fracture Half-Length (ft) [approximate] .620 840 Fracture Total Height (up and down) (ft) [approximate] 197 265 Fracture Width [inches, approximate] 0.37 0.41 14 ppg at 6 BPM Fracture Half-Length (ft) [approximate] 580 790 Fracture Total Height (up and down) (ft) [approximate] 202 271 Fracture Width [inches, approximate] .0.40 0.45 Note: Averages include the cases where only discrete intervals were completed individually. The cases where all of the zones were opened up simultaneously generated fracture lengths and heights considerably less in dimensions. The above table therefore reflects an average of the most extreme cases (most extensive fracture length and height In all cases the fracture was confined to the Torok injection zone. Energy & Geoscience Institute ~' Pioneer Natural Resources Alaska, Inc. Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 Page 5 Case i Completion x Zone Rate (BPM) In ection ~ Fluid Total Volume3 (bbl) Fracture Half- a Length (ft) Upper Heights (~) Lower Height6 (ft) Maximum Wellbore Width (inches)' EO]8 Net Pressure (psi) 5h Shale Shale 6 12.5 ppg slurry 2,500 837 136 95 0.426 197 6a All 6 14 ppg slurry 1,000 Upper 291 97 43 0.21 212 Shale 306 126 48 0.23 169 Lower 460 66 77 0.33 303 6b Lower Lower 6 14 ppg slurry 1,000 643 115 79 0.42 312 6c Upper Upper 6 14 ppg slurry 1,000 545 109 106 0.40 260 6d Shale Shale 6 14 ppg slurry 1,000 548 136 60 0.37 222 6e All 6 14 ppg slurry 2,500 Upper 327 98 46 0.20 207 Lower 383 128 69 0.25 159 Shale 740 129 78 0.40 292 6f Lower Lower 6 14 ppg slurry 2,500 860 202 77 0.44 264 6g Upper Upper 6 14 ppg slurry 2,500 744 109 181 0.43 219 6h Shale Shale 6 14 ppg slurry 2,500 762 136 108 0.47 197 • Energy & Geoscience Institute ~' Pioneer Natural Resources~aska, Inc. . Page 7 uruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) APPENDIX A RESULTS Energy & Geoscience Institute ~' Pioneer Natural Resource~ska, Inc. • Page 8 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Stress Width Profiles Width t'oittoiu's ~. tot I'~ 9b Lmg[li ~0 70 40 60 ~ sn ~'~'~ 9=' 99 I~ ~.~ i~ Ill t { ;r~;1 l;' Irr f t ~,~~ z ,, , .,` , 2000 4000 0000 -0.3 0 0.3 0 100 200 300 400 500 Sh•ess (psi) ~Vicldi (iu.) Leiiatli (ft) Figure A-1. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5a (6 BPM, 12.5 ppg slurry, 1,000 BBL, injection into all three zones (barefoot lower section, upper Torok sand, shale above the shoe). Stress Width Profiles Width C:nntrnu-c 0 0.04 0.08 0.1] 0.16 0.7 0.24 0.78 0.37 0.36 0.4 r~ ~_ A 3000 4000 5000 -0.4 0 0.4 0 200 400 000 800 Sh•ess (psi) Width (in.) Leiiath (ft) Figure A-2. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5b (6 BPM, 12.5 ppg slurry, 1,000 BBL, injection into all barefoot lower section, lower Torok sand). Energy & Geoscience Institute EG' Pioneer Natural Resources~aska, Inc. • Page 9 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Stress Width Profiles Wldtll C.OI1tC~llTS .. ~_ A % Ler~grh ^ 0 ^ ao ^ ~o en ~ © ~0 f ^ ~~ . y~ °- ~~ 2000 3000 4000 -0.4 0 0.4 Sh•ess (psi) VViddi (in.) _ Figure A-3. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5c (6 BPM, 12.5 ppg slurry, 1,000 BBL, injection into upper Torok sand. Stress Width Profiles Width Colltotus x A f~ .nz ^ n3 0 Sh•ess (psi) VViddi (iu.) Leii;tth (ft) Figure A-4. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5d (6 BPM, 12.5 ppg slurry, 1,000 BBL, injection into shale/silt above the shoe). Energy & Geoscience Institute EGI Pioneer Natural Resource~ska, Inc. • Page ~n Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) ___ Stress Width Profiles "'~ '~' "' _ v1 Q E"' S 1 4i Sh~ess (psi) ~~'idfli (n-.) Length (Yt) Figure A-5. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5e (6 BPM, 12.5 ppg slurry, 2,500 BBL, injection into all three zones (barefoot lower section, upper Torok sand, shale above the shoe). Stre~~ Width Profiles Width Contom~s ~, 0 so 40 60 80 90 93 99 ~' Q 51 )0 Sh•ess (psi) lVidtlt (iu.) Lei>_~tli ($) Figure A-6. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5f (6 BPM, 12.5 ppg slurry, 2,500 BBL, injection into all barefoot lower section, lower Torok sand). Energy & Geoscience Institute EG' Pioneer Natural Resources~aska, Inc. • Page 11 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Stress ~'iclth Profiles Widtll C~oirtours A 2000 4000 8000 -0.4 0 0.4 0 200 400 B00 800 Sh•ess (psi) Width (in.) Leiiath (ft) Figure A-7. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5g (6 BPM, 12.5 ppg slurry, 2,500 BBL, injection into upper Torok sand. Stress Width Profiles Width Contours r•-~ ~_ A % Lay ~0 20 ®40 ^ 60 ~~ ~~ 95 ~ 99 zooa 4000 -o.a o 0.4 ~ ~o Sh•ess (psi) Width (iu.) Length (ft) Figure A-8. This is the inferred geometry after flush (displacement volume) at shut-in for Case 5h (6 BPM, 12.5 ppg slurry, 2,500 BBL, injection into shale/silt above the shoe). Energy & Geoscience Institute EGI Pioneer Natural Resource~aska, Inc. • Page 17 Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Sh'ess Width Profiles Wirth (-"nntnnrc ~_ A % Lm ~0 x0 ~ 40 2000 4000 8000 -0.3 0 0 3 _ _ _ Sh•ess (psi) Width (in.) LeiiQth (ft) Figure A-9. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6a (6 BPM, 14.0 ppg slurry, 1,000 BBL, injection into all three zones (barefoot lower section, upper Torok sand, shale above the shoe). Stl'e Wldtll Pl'otlle~ Wirt}i ('nntniirc .ar 0 xo 40 60 80 90 95 99 Q'.r A 3000 4000 5000 ~0.4 0 0.4 _ _ _ Sh•ess (psi) ~'Vidth (in.) Leiisth (ft) Figure A-10. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6b (6 BPM, 14.0 ppg slurry, 1,000 BBL, injection into all barefoot lower section, lower Torok sand). Energy & Geoscience Institute ~G' Pioneer Natural Resources~Raska, Inc. ~ Page 1 'Z Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Stress Widtli Profiles ~'iclth Co~itoius .. Q 2000 3000 4000 -0.4 0 0.4 i Stress (psi) Width (in.) Figure A-11. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6c (6 BPM, 14.0 ppg slurry, 1,000 BBL, injection into upper Torok sand. Stress Width Profiles Width Coiitoius ~_ A 2000 4000 -0.4 0 OA 0 Stress (psi) Width (in.) Lenetli (ft) Figure A-12. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6d (6 BPM, 14.0 ppg slurry, 1,000 BBL, injection into shale/silt above the shoe). Energy & Geoscience Institute EGI Pioneer Natural Resource~ska, Inc. ~ Page id Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) St1-esc Width Profile ~_ A ~ tm ^o ^ ~o ~ ao 60 80 90 95 99 zooo 4000 e000 -o a o o.a ~ Sh•ess (psi) VVidtl~ (in.) Leq~th (ft) Figure A-13. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6e (6 BPM, 14.0 ppg slurry, 2,500 BBL, injection into all three zones (barefoot lower section, upper Torok sand, shale above the shoe). Stress Width Profiles Width C'nntnnrs % Lm D ZO 40 Q 60 80 90 95 ~ 99 ~.' tQt F'I 2000 4000 8000 -0.4 0 0 4 I 10 Sh•ess (psi) `'VidU~ (in.) Leii~th (ft) Figure A-14. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6f (6 BPM, 14.0 ppg slurry, 2,500 BBL, injection into all barefoot lower section, lower Torok sand). Energy & Geoscience Institute EG' Pioneer Natural ResourcesAfaska, Inc. • Page 1~ Oooguruk Beaufort Sea Offshore Drilling Island -Injection into Torok Sand (6 BPM, 12.5 and 14 PPG) Stress R~'idth Profiles ~~'idth Contours W~~ c~ ~ 0 0.05 o~ o ~5 02 0 25 03 0 35 04 0.45 51 Q F" 51 2000 4000 6000 4 0 200 400 600 800 Sh~ess (psi) Width (ua,.) Length (tt) Figure A-15. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6g (6 BPM, 14.0 ppg slurry, 2,500 BBL, injection into upper Torok sand. Stress Width Profiles ~' A % Lcu ^o ^ ~o ^ 40 0 60 ^ 80 90 ®95 ~ 99 2000 9000 -0.5 0 Sh•ess (psi) Width (in.) Figure A-16. This is the inferred geometry after flush (displacement volume) at shut-in for Case 6h (6 BPM, 14.0 ppg slurry, 2,500 BBL, injection into shale/silt above the shoe). Energy & Geoscience Institute EG~ 0.5 0 200 900 600 800 Leii~th (ft) {6J2/2008 1:10:00 AM) 3.4 BBI. m (6/2(2008 3:30:00 AM) 2.0 BBI/mgr Clear Fluid, 8.7 PPg _,.~~~~ ~,~~;~_ ~~.:$.2:z~aa; i LI ~F7_a1302 Pd1302 P6 Di:posd Pump Suction 192.168 BBI/mn 0.0 10.0 \lecmgkpcs32\F9Gde.. 000:00000 ~DI_a 1302 Pd1302 P6 Disposd Punp Suction 192.168. Ib/qal 0.00 16.00 \\scaogkPCr321F8Ga1e. 000.00 [QUO ++PI 910016 D~11001 ~DisD Wel~Fluid From Oceposd Pump 192768.... ps 0.00 35Cb9C I, -: F ;aye D.OOAO WO ^~PI_at00t D~41001 ~DiaD Wel~Anmius Presswe 792.168.... psi 0.(II 1000.OC rir>: ,CS ate. OOU000001 Pioneer Natural Resources Alaska, Inc. Oooguruk AM 6 f2,t"2008 _,~sz.lr~a.u~sl:vr ~IBOU~ [cxd~~} 6 f'2J'Z 008 {6ji1f20D8 3:38:34 PM) 3.4 BB!; (~/11J20085:18:46PM)0.0681;„-~ Slurry, 9.6 ppg -_ _, - _ _~;_ ;,_ _- _` • ;~ • IJ Ei+Ff_11~2 Pd1302 P6 Disposal Pump Suchm 192.168... BBVmn 0.0 100 \\scaogkpcs321FSGate.. 000:00000 D ~+Dt 41302 Pd1302 P6 Disposal Pump Suction 192.168 Ib/gal 0.00 16.E \\scaogkpcs321FSGate. 0.00.000 Pt 910018 D~41001 ~ Uisp Wel ~ Fluid From D ^ isposal Pump 192.168... psi 0.00 3500.00 'ASCaagkpps32\F6Gate... 0.00:00.000 ~ =+P141[gl D~41001~Drsp Wel~NnJUS Hessue 192168.... .--. psi 0.00 1000.W \\sceogkpcs32\FSGate 0: x:00.000 Pioneer Natural Resources Alaska, Inc. Oooguruk PM 6/11/2008 k92.108.1N51:Pt110G18 (C[tlkj 6f ll,f'2008 5+2h~2008 6:2LDB ~'~1) 3.5 8B1/mm (5(26120087:07:32PM)3.OBBIJmm Slurry, 10.4 ppg -0.5 BBljmin;0 da;s, :]'•~~:24j ~,, r~~. ~~.~- _ , ~.I~~ -- - - - __ 3:30:57 PM •x,2]:5'-~1•' S...S-~!,' ---`5-pr,^ n:5~:5~G'1•^ _ 6-- 5j'26,c008 .... 5 ~• T Norte IDeu ion Server Color Urds hlYVnm MexYnun fO Address iima Offset .b Fl_a1302 P~41302 P6 Dsposal Pump Suc~ron 192168. BBVmm 00 100 Uscmgkpcs32lFSGa~e 000.00000 ^J+DI at302 P-e1302 P6 Disposal Pump Sutlron 192-168. Ib/gal 0.00 16.00 \\ttaogkpes32\f9Ga1e. 000:00.000 ~~PI 41001B D~41001~UrspWeO-Fluid ROm Dreposal Pump t92.t68.... psi 0.00 3500.00 \\sc aogkpce321F S G ate... 0.00:00.000 ~~I PI_91001 D~41001-Dlsp WeP-Arrrulus Rescue 192.168.... psi 0.00 1000.00 \\scm9kpcs32\F9Gate. U:OU00.000 r~ • Pioneer Natural Resources Alaska, Inc. Oooguruk {4/10(Z0081D:Z5:48 AM)4,D 65 ° Slurry, 12.4 ppg s 35 10 • i(1D7Z008 :ea.:"s. _: -_.._. 7 PM 4j10/ZD08 IJ W Fl aly0p pJ1 ~2 P6 Disposd Pump Suction 192.160... BBI/min 00 10.0 \\scaogkpcs32\FSGaIe. D00.00000 ^ "~ DI a1302 PJ1302 P6 Disposal Pump 9ucoon 192166. Ib/ 0.00 16.00 \\st ^ _ gal aogkpcs321F5Gale. 0.0000.000 ~++PI 410018 D~41001~Disp Wel~FYxd Fan Disposal Pulp 192168... psi 0.00 3500.W \\scaogkpos32\F9Gale.. 0.00.00 WO 0 ~P7_a 1001 D~41001~DisPWel~AmAus Reasue 192.168.. psi 0.00 100000 \\scapgkpcs321F5Gate. 00000.000 Pioneer Natural Resources Alaska, Inc. Oooguruk {4J10JZ008 6:Zfi:3fi PM) 4.0 BBljrtlin 0.0 BBI(min (0 days, 08:00:48] ~~ • • PIONEER July 1, 2008 NATURAL RESOURCES AWSKA, INC. Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Subject: Oooguruk Unit Development Project Disposal Injection Order No. 31 2007-2008 Annual Performance Review for Oooguruk Unit DW-1 Dear Commissioner Norman: Pioneer Natural Resources Alaska, Inc. (Pioneer) hereby submits an annual performance review for the Oooguruk Development Project disposal well (DW-1), in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) Disposal Injection Order No 31, Rule 6. This surveillance requirement states that a report evaluating the performance of the disposal operations must be submitted to the AOGCC by July 1 of each year and include data sufficient to characterize the disposal operation: • Pressures; • Fluid volumes injected; • Injection rates; • An assessment of fracture geometry; • A description of any anomalous injection results; and • A calculated zone of influence for injection fluids. Pioneer began injection operations on DW-1 on February 25, 2008. Continuous monitoring devices are in place for injection pressure, injection rate, temperatures, and inner annulus pressure. This data is captured electronically, summarized, and included in this report for dates from February 25, 2008 through June 30, 2008. DW-1 Injection Pressures Attachment 1 outlines injection pressure information including average, maximum, and minimum injection pressures on a daily basis. The averages were taken from one-minute readings during injection periods; additional raw data can be provided upon request. 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277-2700 Oooguruk Development Projec• • DW-12007-2008 Annual Performance Report July 1, 2008 Page 2 DW-1 Fluid Volumes Injected Attachment 2 outlines the fluid volumes injected on a monthly basis. This attachment also includes a summary of physical, chemical, and other relevant characteristics of inject fluids. DW-1 Injection Rates Attachment 1 provides average and maximum injection rates on a daily basis. The averages were taken from one-minute readings during injection periods; additional raw data can be provided upon request. Assessment of Fracture Geometry The original simulation at 4 barrels per minute (bpm) and 10.1 pounds per gallon (ppg) predicted fracture half-lengths between 570 and 980 feet with heights of 140 to 230 feet. Based on this assessment with the daily operational information, is reasonable to assume that the fracture geometry and the zone of influence are as outlined. On June 17, 2008, Pioneer submitted a letter requesting approval for a higher injection rate based on a new model with a 6 bpm injection rate and 14 ppg, which shows only modest difference in length and height from the earlier projections (approximately 790 and 270 feet, respectively). The primary effect is fracture width increase. Descr~tion of Anomalous Injection Results A summary of anomalous injection results is provided as Attachment 3. Anomalies in the data are related to various activities associated with routine maintenance and rare instrument malfunctions. For example, on June 11, 2008, there were false readings on fluid density that caused high injection rate readings with no correlating pressure spike data; therefore, it can be concluded that the data was incorrect. Data of this nature has been excluded from daily averages calculations. Calculated Zone of Influence for Injection Fluids In addition to the new model submitted by Pioneer on July 17, 2008 in support of an increase in approved injection rate, baseline temperature survey data has been collected in compliance with AOGCC Rule 6 requirements. No additional, significant data is to be noted for the zone or for injected fluids. The Zone of Influence is believed to be similar to modeling conducted for this disposal operation. A temperature survey conducted on February 18, 2008 showed a constant temperature gradient of approximately three degrees per 100 feet from 4,000 feet to total depth. A second follow-up temperature survey, completed on April 23, 2008 after injection operations had been ongoing for several months, indicated a similar temperature gradient down to 4,990 feet true vertical depth. From 4,990 to 5,070 feet, the log indicated slight warming and from 5,070 feet to total depth, there is significant cooling apparent. The tubing tail is located at approximately 5,076 feet. The significant cooling would indicate that the injection of waste material is contained below 5,070 feet. This may indicate that the fracture zone reaches up to 4,990 feet, which is still well within the arresting zone. However, this is unlikely, as more significant cooling would be expected to indicate fracture growth. Oooguruk Development Proj~ • DW-12007-2008 Annual Performance Report July 1, 2008 Page 3 If you have any questions or require additional information, please contact John Hellen at (907) 343-2102 or john.hellen@pxd.com. Sincerely, . D. Hall Operations Manager -Alaska Enclosures: Attachment 1: DW-1 Performance Evaluation -Daily Injection Data Attachment 2: Monthly Injection Totals and Waste Stream Summary Attachment 3: Description of Anomalous Injection Results Attachment 1: DW-1 Performance Evaluation - Daily Injection Data Date Average Injection Rate Maximum Injection Rate Average Injection Pressure Maximum Injection Pressure Minimum Injection Pressure Average Temperature MfVI/DDIYY) (bpm) (bpm) (psi) (psi) (psi) (deg Fl 02/25/08 3.52 3.52 1679.99 1825.04 1073.21 49.70 02/26/08 No In'ection 02/27/08 1.01 4.20 959.59 1767.14 448.92 92.98 02/28/08 1.72 5.05 1212.48 1812.45 709.04 91.21 02/29/08 1.66 5.13 1255.89 1732.74 716.59 119.00 03/01/08 0.66 4.51 1157.00 1694.14 717.43 62.98 03/02/08 1.93 5.12 1646.15 2451.84 1001.88 92.86 03/03/08 1.55 4.23 1745.50 2492.12 38.60 62.72 03/04/08 1.97 5.35 1498.68 2207.67 757.71 57.87 03/05/08 0.01 0.03 1304.12 2489.60 552.97 64.12 03/06/08 2.10 5.50 1092.30 1869.51 -9.55 70.01 03/07/08 No In'ection 03/08/08 No In'ection 03/09/08 2.21 5.00 1356.33 2066.78 -6.94 72.08 03/10/08 0.01 0.04 1409.53 1687.45 957.44 54.27 03/11/08 2.78 5.20 1299.62 2044.22 703.11 58.36 03/12/08 0.09 0.86 1569.00 2372.33 27.78 47.30 03/13/08 0.66 4.96 223.92 1387.03 -4.34 82.76 03/14/08 3.29 4.94 180.56 1739.45 0.06 92.67 03/15/08 0.01 0.03 301.58 5352.60 -4.20 66.40 03/16/08 0.83 3.67 925.64 1576.66 100.69 03/17/08 0.95 3.78 527.38 1523.80 -12.59 63.05 03/18/08 1.05 3.76 1536.95 2115.36 -5.87 87.18 03/19/08 0.01 0.01 1742.72 2043.20 1484.36 59.37 03/20/08 0.01 0.03 1829.80 2174.10 0.00 59.37 03/21 /08 2.14 4.28 876.12 1980.27 9.23 56.47 03/22/08 2.97 4.19 177.05 1857.76 19.30 50.85 03/23/08 0.75 4.04 644.13 1719.31 41.12 65.68 03/24/08 1.75 4.24 825.93 1714.28 -2.52 62.60 03/25/08 2.02 4.21 1201.67 1750.36 153.55 58.38 03/26/08 No In'ection 03/27/08 1.70 4.06 882.12 1679.87 0.00 78.78 03/28/08 2.11 3.68 1140.39 1814.97 465.70 62.35 03/29/08 1.15 3.62 1730.13 2322.62 771.97 60.91 03/30/08 1.74 3.58 1047.22 2059.98 83.91 63.07 03/31 /08 1.91 4.38 1140.05 1585.89 7.55 81.54 04/01 /08 1.23 3.64 1066.21 1594.29 38.60 62.52 04/02/08 1.20 3.47 943.69 1592.61 39.44 61.74 04/03/08 1.50 3.59 920.00 2085.16 0.00 63.71 04/04/08 0.89 4.41 664.70 2637.28 0.00 55.49 04/05/08 0.83 3.45 532.43 1546.46 72.16 54.35 04/06/08 1.23 3.50 903.00 1533.87 31.05 59.80 04/07/08 2.05 3.45 1035.24 1554.85 20.98 56.79 04!08/08 1.61 3.53 775.07 1496.11 0.00 63.11 04/09/08 1.03 3.43 592.00 1529.67 0.00 59.27 04/10/08 2.13 4.23 571.73 1661.41 0.00 70.49 04/11/08 1.77 4.21 488.65 1612.75 1.68 55.39 04/12/08 0.97 3.68 562.51 1679.87 5.03 51.31 04/13/08 1.47 3.74 1006.11 1595.12 -2.52 63.09 Page 1 of 3 • • Attachment 1: DW-1 Performance Evaluation -Daily Injection Data Date Average Injection Rate Maximum Injection Rate Average Injection Pressure Maximum Injection Pressure Minimum Injection Pressure Average Temperature MM/DD1YY (bpm) (bpm) (psi) (psi) (psi) (deg F) 04/14/08 0.77 3.60 705.77 1647.15 0.00 57.44 04/15/08 0.77 3.59 952.37 1621.14 0.00 56.50 04/16/08 0.99 3.71 461.86 1621.98 0.84 55.08 04/17/08 0.71 3.57 318.23 1652.18 -0.84 57.84 04/18/08 1.06 3.64 633.98 1633.72 4.20 59.07 04/19/08 0.76 3.86 1058.75 1639.60 2.52 59.99 04/20/08 0.01 0.03 961.76 1195.71 719.11 65.87 04/21 /08 0.01 0.03 907.54 1043.84 774.49 65.46 04/22/08 1.33 3.69 1130.54 1856.92 0.00 63.49 04/23/08 0.73 4.00 359.83 2481.21 -1.68 60.40 04/24/08 0.55 3.57 254.56 1478.49 -3.36 65.26 04/25/08 1.10 3.72 528.26 1684.91 -10.91 62.60 04/26/08 1.21 3.84 534.96 1593.45 -10.91 59.72 04/27/08 0.68 3.50 546.21 1594.29 -4.20 59.13 04/28/08 0.01 0.03 773.72 903.71 618.41 64.09 04/29/08 0.99 3.72 568.71 1587.57 22.66 62.56 04/30/08 1.75 3.73 938.93 1657.22 31.89 64.44 05/01 /08 1.35 3.56 890.00 1627.85 7.55 61.46 05/02/08 1.54 3.61 973.09. 1646.31 0.00 59.58 05/03/08 2.21 3.69 1126.21 1601.84 492.55 63.30 05/04/08 1.31 3.63 722.13 1685.75 15.94 58.38 05/05/08 0.81 3.50 462.23 1710.92 0.00 60.11 05/06/08 0.80 3.47 724.20 1705.05 3.36 55.48 05/07/08 1.58 4.50 848.87 1732.74 2.52 64.38 05/08/08 0.09 3.45 389.40 1640.44 -4.20 63.69 05/09/08 1.86 3.59 730.61 1699.17 5.87 59.00 05/10/08 2.27 4.70 880.82 1678.20 5.87 65.08 05/11/08 0.08 3.03 91.16 1664.77 4.20 63.21 05/12/08 0.00 0.00 0.00 0.00 1.00 0.00 05/13/08 3.22 3.49 1484.29 1730.22 426.26 54.92 05/14/08 1.74 3.47 802.65 1710.08 -4.20 57.28 05/15/08 3.38 3.38 1466.74 1466.74 1466.74 50.69 05/16/08 2.65 3.53 1195.87 1648.83 -3.36 50.06 05/17/08 1.21 3.53 601.39 1647.99 2.52 60.26 05/18/08 0.80 3.50 408.78 1647.99 -4.20 57.84 05/19/08 1.03 3.50 535.03 1694.14 -5.03 61.03 05/20/08 1.11 3.57 518.83 2961.18 -4.20 62.74 05/21 /08 0.63 3.51 306.53 1720.15 0.00 59.67 05/22/08 0.88 3.58 507.24 1700.85 6.71 63.31 05/23/08 1.31 3.62 788.63 1726.02 -1.68 55.29 05/24/08 1.15 3.57 586.76 1710.08 -7.55 60.66 05/25/08 0.81 3.52 420.85 1728.54 -9.23 62.44 05/26/08 1.35 3.59 901.46 1736.09 -5.03 60.11 05/27/08 1.15 4.45 765.33 2596.17 -5.87 61.52 05/28/08 0.64 3.46. 484.80 1707.56 2.52 61.59 05/29/08 0.77 3.67 436.26 1745.32 0.84 60.81 05/30/08 0.92 3.48 466.75 1570.79 -5.03 58.90 05/31 /08 1.23 3.75 692.59 1590.93 0.00 58.75 06/01 /08 1.00 4.74 573.53 1689.94 -12.59 59.59 Page 2 of 3 • Attachment 1: DW-1 Performance Evaluation -Daily Injection Data Date Average Injection Rate Maximum Injection Rate Average Injection Pressure Maximum Injection pressure Minimum Injection pressure Average Temperature MM/DDJYYj (bpm) (bpm) (psi) (psi) (psi) (deg Fj 06/02/08 1.68 3.62 826.09 1592.61 -3.36 57.02 06/03/08 0.63 3.56 275.50 1580.02 -3.36 62.20 06/04/08 0.73 3.51 364.51 1574.15 -1.68 68.92 06/05/08 0.24 3.44 225.12 1601.00 -3.36 61.14 06/06/08 1.21 4.48 761.98 2623.02 -1.68 58.70 06/07/08 1.08 3.51 559.45 1767.98 -1.68 56.72 06/08/08 1.26 3.57 648.17 1781.40 -1.68 59.79 06/09/08 1.40 3.51 730.46 1752.87 -4.20 64.78 06/10/08 0.01 0.05 -2.80 2.52 -4.20 60.61 06/11/08 1.60 3.51 747.38 1770.50 -4.20 61.34 06/12/08 2.11 3.77 925.49 1787.28 -5.03 59.22 06/13/08 1.44 3.59 707.48 1788.96 -5.03 64.89 06/14/08 0.46 3.59 232.73 1784.76 -5.03 60.13 06/15/08 1.26 3.55 657.81 1835.95 -7.55 64.93 06/16/08 2.42 3.56 1178.19 1756.23 -7.55 73.00 06/17/08 2.42 3.56 1178.19 1756.23 -7.55 73.00 06/18/08 1.89 7.62 592.56 1743.64 -6.71 60.00 06/19/08 1.07 4.15 495.48 2836.15 -3.36 62.42 06/20/08 1.58 3.57 1093.27 1820.00 9.23 59.98 06/21 /08 1.16 3.52 624.27 1843.50 5.03 60.43 06/22/08 1.45 3.98 1081.80 4885.23 -3.36 63.20 06/23/08 0.44 3.44 1270.73 1404.65 1128.59 64.59 06/24/08 1.09 3.50 1239.96 1920.69 5.03 60.54 06/25/08 1.22 3.55 1006.00 1768.82 5.03 59.11 06/26/08 1.25 3.51 747.49 1742.81 -1.68 61.02 06/27/08 1.51 3.62 851.46 1757.91 1.68 57.85 06/28/08 1.33 3.49 1017.03 1744.48 5.03 61.99 06/29/08 1.24 3.50 821.81 1747.84 8.39 57.68 06/30/08 1.05 3.54 672.72 1747.00 3.36 .60.61 Page3of3 i • Attachment 2: Monthly Iniection Totals and Waste Stream Summa 2008 Monthly Injection Totals Month Volume of Injected Fluid (BBLS) February 4,801 March 29,950 April 28,989 May 44,355 June 37,714 Physical, Chemical and Other Relevant Characteristics of the Injected Fluid Non-Exempt Typical primary Constituents Sampling Conducted or Waste Streams Non-Exempt Sources Generator/Process Knowledge • Incidental non-hazardous wastes generated Wash water, seawater used for by module operations & maintenance drilling mud make-up, Potable U1-Utility Module Sump -Sampled on Utility modules sump Incidental equipment leaks water chemical additives. 3/11/08 -Sump Fluids were not RCRA- fluids •Additives for Reverse Osmosis & potable Process control is strictly hazardous water systems maintained Glycol /heat exchange media .Vehicles & equipment (antifreeze) Glycol (MEG, DEG, TEG, propylene) Glycol -Not injected year to date Non-exempt spill Fluids recovered from cleanup of non- Water, snow, gravel, with Spot Clean-up Gravel -Sampled on exempt spills hydrocarbon or chemical 1/29/08 -Spot cleanup snow/gravel were clean-up • Spill impacted gravel or snow products not-RCRA hazardous Hydrotest fluid • Pressure test new or non-exempt process Water, glycol, possible product Hydrotest Fluids -Not injected year to (water or glycol only) lines, vessels residual in existing lines, traces of date chlorine or other biocide Boiler blowdown -Not injected, fluids Boiler blowdown .Rig or production facility boilers Water used for drilling mud make-up water Grout wash water -Sampled on 9/12/07 - Offspec product • Products spilled, out-dated or no longer Varies -MSDS reviewed Grout wash water was not RCRA- acceptable for original purpose hazardous Contained snow / • Outdoor containment around fuel and Water, possible traces of Secondary containment water -Sampled on 5/20/08 - analysis on ponded water chemical storage tanks hydrocarbon or chemicals if there impoundment/stormwater w/ sheen was .Depressions on or between pads & roads have been spills shown to be not RCRA hazardous Lubrication Oils -Not injected - • Motor oil Usually sent to hydrocarbon recycle, Lubrication oil .Transmission fluid Hydrocarbons/water mixes- Flashpoint and or benzene analysis • Hydraulic oils typically conducted • Internal or external washdown of skids, modules Water, possible traces of Facility wash water- Not Injected year to Non-exempt facility .Equipment cleaning (using non-hazardous hydrocarbon, chemicals, date, Generator knowledge and/or MSDS wash water detergents or degreasers) detergent or characterization conducted • Residues removed from RCRA-empty containers z Incinerator ash • Trash and camp waste particulates/RCRA metals Incinerator Ash -Sampled on 4/17/08 - • Sewage sludge Shown to be not RCRA hazardous Domestic wastewater .Camp wastewater treatment plant(s) and Water, soap residuals, human Sewage Sludge -Generator Knowledge - / sludge site enviro-vacs waste non hazardous Reverse Osmosis • Saline concentrate from reverse osmosis Seawater Concentrate -Generator concentrate/Seawater Process for making potable water from Saline water Knowledge -non-hazardous seawater 1. Note that similar wastes may be RCRA exempt, depending on waste-generating process. 2. Waste streams that were not generated or injected during a particular quarter are not usually sampled Page 1 of 1 Attachment 3: Description of Anomalous Injection Results Date and Time Anoma) and Ex lanation 2/25/08 17:48 Start of Injection 3/14/08 16:34 Invalid Injection Pressure: No injection bein done at time of readin 3/15/08 8:08 Invalid Injection Pressure: Gages were not reading correctly, Work being done on the pump to seat the valves. 3/24/08 19:28 Invalid Injection Rate: Rate is not possible or consistent with surrounding data 3/27/08 13:38 Invalid Pressure Readings: Gages not reading correctly, reading is not consistent with surroundin numbers or with revious in'ections with the same fluid at the same rate. Invalid Pressure Readings: Little to no injection and pressures above and below do not 4/12/08 14:19 correlate with the other data given Invalid Injection Rate Reading: No pressure spike related to the injection rate reading, giving 4/30/08 13:56 a false high Invalid Flow Rate Reading: The reading is a even number with no decimal and above the 5/18/08 14:50 capability of the pump, showing that there is some kind of error for this period. Invalid pressure reading: No build up to values before and after significantly less pressure 5/20/08 16:39 and no significant fluctuations on flow rate to cause pressure increase. Incorrect Density Readings: If the density was reading correctly then the flow rate would 5/30/08 23:53 reflect the correct value Incorrect Density Readings: If the density was reading correctly then the flow rate would 5/31/08 3:12 reflect the correct value. Incorrect Density Readings: If the density was reading correctly then the flow rate would 6/1/08 1:54 reflect the correct value. Incorrect Density Readings: If the density was reading correctly then the flow rate would 6/1/08 3:30 reflect the correct value. Incorrect Density Readings: If the density was reading correctly then the flow rate would 6/11/08 18:56 reflect the correct value. Incorrect Density Readings: If the density was reading correctly then the flow rate would 6/13/08 21:49 reflect the correct value. Invalid Readings: Working on pump. No density or injection pressure spikes are correlated 6/18/08 0:58 to the high flowrate. 6/19/08 7:51 Invalid Pressure Reading: No flow rate associated with this pressure. XV valve not open. Invalid Pressure Readings: Flow Rate and pressure do not match. There was no increase in flow or density that correlates with sudden pressure spike. Pressures before and after 7 6/19/08 19:49 minute interval are more them 500 si different. 6/24/08 22:04 Invalid Pressure Readin :Inconsistent ressure readin with the surroundin ressures 6/25/08 7:58 Invalid Pressure Readin :Inconsistent ressure readin with the surroundin ressures Incorrect Density Readings: If the density was reading correctly then the flow rate would 6/28/2008 4:34 reflect the correct value. Page 1 of 1 #5 Oooguruk Disposal Well . . Jim, Following up on our phone call, Pioneer will be monitoring several injection well parameters, including pressure and flow, through the digital control system. The DCS will have alarm setpoints and will record the parameters at a frequency adequate to track well performance. I've attached several P&IDs showing the system. Let me know if you have any more questions. John Hellén Regulatory and Environmental Coordinator Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600 Anchorage, AK 99501 907 343 2102 office 907 343 2190 fax john.hellen@pxd.com Content-Description: 04802-4-DG-BC-00009.01rev01.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 04802-6-DG-BC-00001.07rev01.pdf Content-Type: application/octet-stream Content-Encoding: base64 Con tent-Description: 04802-6- DG- BC-00005. 02revO. pdf Content-Type: application/octet-stream Content-Encoding: base64 04802-3-DG-BC-00001 1 of 1 Content-Description: 04802-3-DG-BC-00001.03revO.pdf Content-Type: application/octet-stream Content-Encoding: base64 6/7/2007 12:23 PM "'-. ;0 a. 1J ::I ~~o "- a ~ ë I "'.- f'") 02 oa." ... '" g~ /.a ~~I ~'g~ ~(I),¡,; QaJO ~IO a.(I)(I) I w.§ -WQ 10 ~~ I CD ÞIO <DU!. o~o 10.2 ~o..~ ~ 1:3 g~~ Na. ç:"ool Q!~ '" 0 ~8E 00": /N.s::. .................. ~~~ ""'N E '= O-ÖW Z2t: ~:2~ ,,-a.::> . MOBI.t MUD 14-oC-BC-00003.o1 ~ FROM P-10401 6"-OM-A-C1-1oo7 BASE OIL 13-oC-BC-00004.o2 ~ FROM P-17401 4"-BO-A-C1-1014 FLUID SWÞP 14 DC BC 00005.01 ~ -IRQILj'-10403_ _ _ _ __ --- ~ MUD RETURN FROM RIG 4" BM-A L1 1OO1-2F-E "" 14 DC BC 0000201 ~ .L ~-----~-- BRINE TRANSFER 6" -BR A C1 1003 14 DC BC 00008.01 ~ FROt.t P-1S401 6" FS A-C1-1OO3 LSND/GEL MUD 14 DC BC 00004.01 ~ FROM P-I0402 BULK GLYCOL 14 DC BC 00007.01 ~ FROM P-17403 BULK LUBE 14 DC BC 00006.01 ~ FROM P-17402 6" LS A C1 1005 4"-MA-A C1 1003 4" LO A C1 1003 - - - - - - r-S"-CC-A-L1-1001-2F-E CUTTINGS TRANSFER J"" 14 DC BC 00002.01 "" FROM RIG 2F-E ------- FLOW BACK 16-oC-BC-00007.o1) 4" -CO-A-N2-1 004 DRILL WATER 14 DC BC 00001.01 FROM P-4540 1 A/B 3" PW A N2 1006 OWG.No TITLE REFERENCE DRAWINGS 4"-BM-A-CI-1001 S"-CC A C1 1001 t .... o o í N Z , <: , if " '" - DRIWNG FLUIDS RSC CONTRACTOR II (NOTE 2) II II II II II II II -I "" 0 0 í N Z , <: , ~ "- I 'h I I II 1 II II Z-10101 ~ (NOTE 1) (NOTE 7) l' <t>- nn I I P-10101A/S I I I I I I I Z-10101 MIX PITS I I I I L___ Z-16101 CUTTINGS REINJECTION 00 (NOTE 1) - P-16101C/O ÇÐ.4ENT MIXING UNIT I 07FE821 ECA MA REISSUED FOR CONSTRUCTION 0 06 OCT 15 ECA 1VF ISSUED FOR CONSTRUCTION 06 06AUG18 ECA rYF iSSUED FOR REVIEW 04 06 JULOB ECA TVF IssuED FOR REVIEW 03 Q6 APR 24 eFG JAS ISSUED FOR SAFETY REVAUDATION No OATE OWN CHK'O DESÇRIPTION ISSUES / REVISIONS r-w (NOTE 8) : / " rxs\- -1 ,......,......, ~ - - '--J'o.J ¢- n n JCP-06-770 MIX PITS CONTROL PANEL (NOTE 4) ¢----- JCP-06-771 CUTTINGS REINJECTION UNIT CONTROL PANEL (NOTE 5) - Z-16101 cumNGS REINJECTION UNIT ORILLING FLUIDS CONTRACTOR RSC II II II II <þ(NOTE 6) I~ I- -I XL) I~ I I II I I- -c::J:I ~ ~ (NOTE 8) (NOTE 2) 4" CC A N2 1002 13"-CM-J-L1-1001 II - ~ - - - - - -RlGSUPPoRrIMA "" 4" BM A L1 1002 2F-E MUD SUPPLY TO RIG 4 DC BC 00002.01) 4"-BM A CI 1002 L.::J ~--------~ 6" OM A C1 1001 MOBM MUD · 1 4 DC BC 0000301) TO H0401 AjB/C FLUID SWAP .. I 4 DC BC 0000501) TO T-10403 LSND/GEL MUO · I 4 DC BC 00004.01) TO T-10402 BRINE TRANSFER · I 4 DC BC 00008.01) TO T-I5401 6" FS-A-C1-1oo1 6" LS A C1-1OO1 6" BR A-HO-1OO1 NOlES: 1.) EQUIPMENT PROVIDED BY HAWBURTON. 2.) ALL CONNECTIONS TO DRILLING FLUIDS IN CONTRACTOR AREAS ARE 1SO# ANSI RF FlANGES. 3.) 3/4" POTABLE WATER CONNECTIONS TO MIX PITS AND CRU NOT SHOWN FOR CLARIlY. SEE SHEET 4-DG-BC-00010.01. 4.) ON/OFF PUSH BUTTONS WITH ACTIVATION LIGHTS ON PANEL WILL BE LOCATED AT MIX PITS (Z-10101) TO CONTROL TRANSFER PUMPS FOR MOBM, LSND/GEL, FLUID SWÞP, BASE OIL, BRINE TRANSFER, BULK GLYCOL, BULK LUBE, AND DRILL WATER. PANEL BY RSC. 5,) ON/OFF PUSH BUTTONS WITH ACTIVATION LIGHTS ON PANEL WILL BE LOCATED AT CUTrlNGS REINJEcnON (CRU) UNIT (Z-16101) TO CONTROL DRILL WATER AND FLOW BACK PUMPS. PANEL BY RSC. 6.) BOTH CRU AND MIX PIT CONTROL PANELS WILL HAVE ONE BEACON AND AlARM FOR TANK OVERSPILL WARNING. BEACONS AND ALARM BY RSC. 7.) SID OF MIX PIT AND CRU THROUGH HALLIBURTON MCC - 1 ClASS C CONTACT REQUIRED. 8.) HORN SILENCE. SRK TVr JAS RCB SRK TV' JAS RCS TITLE SRK TV' JAS RCB SRK TV' JAS RCB DRAFT CO-ORDINATOR LEAD DISCIPLINE ENGINEER ENGINEERING APPROVAL PROJECT ENGINEER PROJECT MANAGER DATE CLIENT APPROVAL DWN.BY CLIENT SCALE CUTTING SLURRY · 16 DC BC 00001.07) FROM CRI TO WASTE SLURRY TANK OR DISPOSAL LINE ~_____ _n 3"-CM-J-L1-1OO1-2F-E CEMENT TO RIG "" '-' 4-oC-BC-00002.01 --~--- k"'2!"'/'M!~"""""%~,,,,,~,,"''''='ill'''''''':'''::~<:"':::.i::":&-""b,~;,;-;·.;;;:;"j EElS CONSULTING ENGINEERS, INC. f_,,,,_,·,,j;"':'.(""""'~~\";'~\( ~,'-'~'~"; ;"'''''~,~.:.~§ii:~;;::;:;):m'''''~:''"] 205066151 PIONEER NATURAL RESOURCES OOOGURUK PRODUCTION AND DRillING FACIUTIES OFFSHORE MIX PITS HEADER PIPING AND INSTRUMENTATION DIAGRAM (P&ID) JAS DATE TOE/EElS owe.No 2006 APR 05 04802 4 DG BC 00009.01 I'" I 1 CADD fiLE CLIENT OWe.No. NTS - - T-41402.\IB P-41402.\IB WASTE SLURRY TANKS WASTE SLURRY PtIWS SIZE: 12'-0" 00 x 30'-0" H CAPAClìY: 800 GPM @ 90' TOH CAPAClìY: 600 BBLS (EACH) POWER: 60 HP INSULATION: 2.5 H (2 x 100%) CONNECTIONS: 6" X 5" ~-~-------------- 4'-CC-A-NZ-I004 . TO FLANGES. > METHANOL FROM METHANOL BOOSTER PUMPS 6-DG-BC-00008.01 I (P-38401A/B) ------- ----- I JIIIEI: 11.) ALL EXTERNAL VENTS, LIT TANK NOZZL£S, AND REUEVlNG DEVICES ON TANKS TO BE INSULATED AND HEAT TRACED. Z.) TWO ELECTRIC HEAT TRACE CIRCUITS (PRIMARY AND SPARE), SKIN TEMPERATURE CONTROlLED. I J.) INSTRUMENT OR DEVICE TO BE MOUNTED INSIDE PIPEWAY. I 4.) DlSPLAY/READOUT TO BE MOUNTED IN TANK WINDOW FOR OPERATOR VlSlBlLIlY. 5.) BIRD SCREENS TO BE INSTALLED ON ALL TANK VENTS. 160) TRANSMITTERS MOUNTED ON TOP OF TANK(S) TO BE INSTALLED IN UNHEATED ENCLOSURES. 7.) BLUE BEACON - FlASHINC UGHT INDICATES TANK WARNING AI.ARII OR TANK EMERGENCY AlARM. 8.) HEAT TRACE CONTROLLER TO BE LOCATED IN MCC MODUL£. : 9.) ~~: ~~~~1'~~" :U~WN 110.) IE~: :f:Xl0~0:5~~~U~~N I 11.) TANK(S) EOUIPPED WITH INTERNAL ZINC ANODES FOR CORROSION PROTECTION. 1Z.) PUSH BUTTONS AT PUMPS. 1 J.) MMI AT DISPOSAL/INJECTION PUMP. 14.) LOCATED ON CA1WALK NEAR TOP or TANK. 15.) LINE SIZE CHANGES AT J', 4', ANO ~ DISPDSAL FLUIDS DISPOSAL PUMPS 6-DG-BC-00005.02 (P-41302A/B) DIESEL TRANSFER PUMPS 3-DG-BC-00004.04 I (P-61402A/B) WATER FROM DRILLWATER TRANSFER PUMPS 4-DG-BC-00001.01 (P-45401A/B) WASTE FROM LIQUID WASTE PUMP 6-DG-BC-D0001.06 I (P-41401A/B) BOLTED REDUCING 4" -CD-A-NZ-I069-2F-E 4"-ME-A-CI-I00J WITH ~ "" ~ .!. .... , I § I ZF-E ï .... Z I -< , Q (,, , I .... i_ -'1]1- - --- 'R ' "'H~'" ~NU 1 1 « « 4' 4' [I---IIX:O 4'-DF-A-C1-1019 A5RS-N2 AJRR-NZ NC £~ :z u 1 1 « « 4' . ~ A5RS-NZ AJRR-NZ NC 4'-CD-A-NZ-1071 4' -CD-A-NZ-10Z7 MADE ARE 4' 4' 14-t,1~1 A5RS-NZ AJR~ëN2 -----.-- NOZZLES 4" 4" 1+-IV1~1 A5RS-NZ AJRR-NZ NC TANK 6' I I I I .... z , '" '" ~~ ~¥ -~ :B ~ I N z: , -< , Q (,) .' ... 1077 DIXR-N2 0, J) HAlUBURTON ~T_ ~ST 41402A-A I 41402A-C (;£\ SP I ~SP 41402A-B I 41402A-0 '----' I ~ (NOTE 12): i ~.~ ~ --.J ~ ~ '~(NOTE 13) I fPì'\(NOTE J) I 41422A I I 1 XR-NZ 6' 6' 6' ~ IX:OI ¡ I A5RS-NZ § AJRR-NZ AJRR-N2 3/4' 3/4' D2SF -SI D2SF-S1 P-41402A I TYPE I M.4 ~T_ (Hs\ST 41402B_A141402B_C (;£\SP (;£\SP 414028-8 414028-0 '----' Y 0 (NOTE 12) I ~ . I .... E MCC ~ ~ <Þ- 41402B· I (NOTE 13) ¿, (,, fPì'\ (NOTE 3) ~ : ~41422B I 3/4' D1XR-N2 6' 6' 6'. 6"-CO-A-NZ-1068~ NI-;¡;-IIX:OI---Þ IX:OI I A5RS-NZ § AJRR-NZ AJRR-NZ ¡ 3/4' 3/4' DZSf"-SI DZSf"-S1 P-41402B ]~E I 6' -CD-A-NZ-1079 RIG SUPPORT AREA :-MsP:==A~_ I '~E 'VI : PUSHBUTTON LOCATED : , ON CATWAlK NEAR TOP I , or TANKS TO STOP I : CUmNGS REINJECTION 1 I PUMPS (P-16101A/B) 1 L__________...J 2' taJl AZRR-L2 Jî'( ~ - - 41412A-B ~ /'----', (NOTES 7, 14) Jî'( <Þ- - - )1~~ (NOTE 8: <þ (NOTE 4, 7) ~. 1- 4~ I : (NOTE ~____ I ~__n :® T-41402A 1 Is / 327 I , :@ 4· "" ; !'IN - & ~N~ ~ . HZO !!! 5! , .... z t Q (,, .' <D 1 1 1JN6\ T -41402B I 3" 1\::/ I Is / 327 I . :8 4' "" §_; ~ § 337 8 (NOTE 1 SET . z· [X)I AZRR-LZ ª I .... z .I: , 8 , ;; ... ~. I ~ I -< I ~ .' '" 4" -CC-A-N2-100.2 ª I ::::¡ I -< I z: ;;- N NITROGEN SUPPLY 4-DC-DG-OOOlO·017 Z· -IN-A-1I-1006 '" z -' .~'" "'1 ~ -·S !f '" '" ~ CUTTING SLURRY FROM Z-16101 4-DG- BC- 00009.01)- CUTTINGS REINJECTION MODULE (CRU) IllS CONSULnNG ENGINEERS. INC. RCB RCB RCB RCB RCB JAS JAS JAS JAS JAS RCB 1VF 1VF 1VF 1VF 1VF RK RK RK RK RK JAS 1 "' ----, PIONEER NATURAL RESOURCES OOOGURUK PRODUCTION AND DRilLING fACilITIES OFFSHORE WASTE SLURRY FACILITIES PIPING AND INSTRUMENTATION DIAGRAM (P&ID) DATE 2005 AUG CADDFlI .07 1 TOE/EElS DWG.NO 04802-6-DG-BC-OOOO 09 ELT NTS " WN,BY s CLIENT DATI PROJECT I.1ANAGEI ON' PROJECT LEADDISCIPlI ENGINEER DRAn MA TVF TVF JAS JAS JAS CHK' 'I 15 18 CA ECA ECA ECA ECA CFe JAS JAS LWM OWN. 08 30 " 20 13 o AI F DAT FI 0' AJJ' UI 07 06 06 06 06 06 06 o D6 D5 D4 D3 D2 DI C1 No. " - DWG.No. 01 .. ., 0. "'.3 :!~O "- .. 0.. c I CJI'Õ a~-¡; ... II: 81~ ~~ I ~.~~ (/) en .. /" I.!! DIDO ~I<X Q.!!1E .!.~ë ~ Q; I ~!'-1t'J CD.,· °ÕO ~ä:.!! /" 18 It") VI ~~~ ç", I z~"'O ~-o a::I"E ::>00{ ~~:5 ~ ;;, .8 .........0 ., '" N g.;;~ Z Q).. - ~ CUÕ~ ~ä::J . ~ DISPOSAL wn.L I--- - - - - - - - - - - - - - - - - - --.- - - - - - - - - - - - - - - - - ':'" ---- - - - - - - - - - - - - - - - - - - - - - --l (Pi) 4!.,OO1A [ ~ - [><II sa 3/4' ~'\... PiiS1 G1XR··C2 'V"{/ -o.~ ~ I I C8W-51 ! T r.=J. ' 3/4' ~ wre~~t .~~ 13[f\ FC Is/ 414 I 3 1/8 API 6A ASM£ 5000# 831.4 (VETCOGRAY) (ToE) I G-C2 ~ 3/4' G1X¡;-C2 3' VlI J5CS-lN2C 1::>- "'<>.01 ..ç~~j/ :·K¡\;'ff., \.fP !\~ ..-- '--" -' ~,¡;¡ ~;L 3' '12 3 4' G1XR-C2 ì ~ .~.. C 1 XR--C2 3' -DP-C-C2-1OC1-2F-E DISPOSAl FLUID ~ROM DISPOSAl P\.iMP (6-OC-BC·OOOOS.Ol! (P-413D2 AlB) I I ~. I tii: I I I INSIDE I OUTSIDE T I I I I I >--_____________________________________________________ WE~ M~~J ~ 1.) 4B TYPICAL WELLS WITH INiTIALlY 22 PRODUCERS, 17 WATER I"JECTORS AND 1 DISPOSAL 2.) TIiERE ARE 4 WEllS PER MODULE, 3 MODUlES PER BAY. MID 4 'JAYS IN TOTAl. ¡[:M~~ff;ft·f."".-~"'~ t ì~;-!t'(ß "J 1_.. -aJrI\! l .\.&¡J~''i' I ~-~~i -- ".' "- 0 G"IP 21 L.WII 100 ISSUED FOR CON5TRtJCIION 100 ~-- -~-.. .--.---....._. -_.~ ..- "-"n_ <>'-"'-"'-.-~-- OJ ...ilia lWII 100 ISSUED FOR moJII:N1I.. .x;p ~_.--'^ 02 GUPII 2< lWII C.JG I&SUEO FOR SAFE1'I HE-VNJUIIIION oIGP 0' .. 10 17 .Ill: Elf ISSUED !'OR _ .. . _. ........_.--...._--- B2 œllØf21 JZC ELf ISSlÆD FOR DECEIIIIER = tlAZOP Jl!l' B' œ!Ð 12 100 ELf ISSlÆD FOR SEPT. 2005 ESTIMATE Jl!l' .- '-. /oJ 115 HJO 15 JZC Elf ISSUOI FOR HAZOP 100 K2 OUJl.2I Cl 100 ISSlJ(D FOR _ RE\IEW <JaØ( ...- .-..--. CO-=~mR No. ....... .... C1I<'. DESCRP!1ON - - -_...._--- ISSUES I REVISIONS . --_.'- ---- ------. --,-_._~-,_....__. - -.. -. -- - _._--_._."--~..--- _____~~~__ _L__._." REFERENCE DRAW1NG5 1I11.E - ~',~"._--~ ilK 1\.1) GAS 1\.1) II< n.o II< Bill' lIlT - RICA 11II< lIlT I 1\.1) \ SGH ~ ~§~© ~(Iï)~~W~@f7"Wð©Gi)@ ~'7Ip Wi @@¡CIìIIàIIh) ~ØiIaiI®II'IIIiI® \h,~. . PIONEER NA lURAl RESOURCES ~ OOOGURUK PRODUCmOH NIl) ORIWIC FACIUÆS OFfSHOREWELU£AD AND MANIFOLDS DISPOSAl WElL PIPING AN[U~ENTATION DIAGRAM (Pc!cIO) DØ[ fOl OIfIG.NcI. JZC 2005 JUN 18 04802-3-DG-BC-00001,03 ¡..v. I 0 I ."-".~--- ----- .. .-- ~ SIt SIt MWP - u 1I11.E - -- _BY ---> I DH I \ I.W=~__ ':.ROÆCI' r.to.'ClNœt: l'~ECT MANlCEJt mt ;x:<..... _ERIHG A"!'RCllII.. 0...," CLiENT -~~,~..- .. ""'" CllDD F1..[ t:t.l':Jff DWG.NI:I. lIlTS 00103-0CYA CUEN:" APPROVAl #4 Oooguruk Fracture Report . - Here's the complete fracture report. I talked to Temple. She tells me that they do not normally receive the disposal well applications, nor do they request them. I offered to send her this one but she declined. Let me know if you have any more questions. John Hellén Regulatory and Environmental Coordinator Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600 Anchorage, AK 99501 907 343 2102 office 9073432190 fax john.hellen@pxd.com Content-Description: Appendix A.pdf Content-Type: application/octet-stream Content-Encoding: base64 10fl 5/1/2007 9:41 AM · - Simulation of Slurry Injection: Ooorguk Beaufort Sea Offshore Drilling Island Injection into Torok Sand Prepared for: PIONEER NATURAL RESOURCES ALASKA, INC. 700 G Street, Suite 600 Anchorage, Alaska 99501 Prepared by: ASRC Energy Services E&P Technology, Inc. AESET-07-Rl January 2007 - . TABLE OF CONTENTS I. Background........................................................................................... 3 II. Matrix of Simulations............................................................................ 3 III. Resu Its. . . . .. . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . .. . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . .. . 5 Appendix A (Input Parameters)..................................................................... 10 Appendix B (Waste Stream) ......................................................................... 23 Appendix C (Results)...... ............... .............................................................. 26 - - BACKGROUND Pioneer Natural Resources is considering injecting cuttings slurry into a dedicated disposal well in the Oooguruk Beaufort Sea Offshore development drilling island (Oooguruk Drill Site (ODS». Hydraulic fracturing simulations were carried out using commercial and proven software (MFrac™) to assess the evolution of fractures associated with injection into this well. The location of the well is in State of Alaska waters approximately 6 miles offshore in the Beaufort Sea, near the mouth of the Colville River. "The Class I well is planned as a straight hole vertically below the island."l "Injection would be into the Torok Formation at approximately 5030 feet. There would be 48 development wells. The fluid would typically be well treatment and workover fluids and drill cuttings and mud. Minor amounts of non-exempt, non-hazardous liquids would be disposed of; mainly camp wastewater treatment plant effluent, camp gray water and the island sumps that catch storm water."l A MATRIX OF SIMULATIONS Appendix A summarizes the input material properties. provide between 12,000 and "'15,100 bbl of slurry. Appendix B. A typical new well would Estimates are provided in The variables adopted in the simulations were: · Four completion schemes. Perforations are shown in Figure 1 and Table 1. They are based on the offset logs from Kalubik #1. A barefoot completion is planned. It would be possible to move uphole and complete with perforations in the upper part of the Torok if the barefoot section becomes filled with solids. The well is assumed to be straight hole. Table 1. Perforated and Barefoot Intervals Measured Zone Depth of Comments Depth of Perforations Perforations (feet TVD RKB) (feet RKB) 5009.5-5105.5 1 5009.5-5105.5 Perforations (Upper Torok Sand) 5164.5-5269 2 5164.5-5269 Barefoot (Lower Torok Sand) Initial simulations did not discriminate any preferential zone - i.e., it was considered that injection was into the entire Torok sequence, including the intermediate shale as illustrated on the following schematic. 1 Oooguruk development Project - No Underground Source of Drinking Water Ruling Request, August 8, 2006. k 1 o A barefoot indude If Cases are run for various . . Subsequent simulations looked at more specific injection situations. The four situations considered were as follows. 1. Injection into the entire Torok interval (open to injection from 1V5009.5 to 1V5269 ft through the perforations indicated in 2) to 4) below. 2. Injection into the Lower Torok sand (barefoot 5164.5-5269 ft) 3. Injection into the Upper Torok sand (perforated 5009.5-5105.5 ft) 4. Injection into the intermediate shale (5105.5 - 5154.5 ft). . Three fluids were used in the simulations. These were neat produced water or seawater (no solids) at an estimated temperature of 70°F (at the sandface), a 9.5 ppg slurry [equivalent to a base fluid with approximately 1.5 ppa (pounds of proppant - solids - added)], and a 10.1 ppa slurry [equivalent to a base seawater fluid with approximately 2.4 ppa solids]. Power law rheologies for these fluids were specified and these are shown in Table 2. Table 2. Fluid Rheology Fluid n' K' Weight Specific (lbf-sn'/~) (ppg) Gravity SeawaterjPW (base fluid) 1.0 1.313 x 10-5 8.66 1.04 9.5 ppg slurry 0.7 1.022 x 10-3 9.5 1.14 10.1 ppg slurry 0.7 7.156 x 10-3 10.1 1.21 . Several schedules were adopted for assessing slurry injection. Various parametric simulations were run and key results are reported for the following scenarios. 1. Case 1 (Base Case):," a. 1000 bbls of 9.5 ppg slurry with a spearhead and flush at 2.5 BPM. b. 2500 bbls of 9.5 ppg slurry with a spearhead and flush at 2.5 BPM. 2. Case 2: a. 1000 bbls of 9.5 ppg slurry with a spearhead and flush at 4 BPM. b. 2500 bbls of 9.5 ppg slurry with a spearhead and flush at 4 BPM. 3. Case 3: a. 1000 bbls of 10.1 ppg slurry with a spearhead and flush at 2.5 BPM. b. 2500 bbls of 10.1 ppg slurry with a spearhead and flush at 2.5 BPM. 4. Case 4: a. 1000 bbls of 10.1 ppg slurry with a spearhead and flush at 4 BPM. b. 2500 bbls of 10.1 ppg slurry with a spearhead and flush at 4 BPM. The methods for developing the input data are included in Appendix A. A RESULTS Results of the fracturing simulations are summarized in Table 3. Figures for the various cases are provided in Appendix C. Based on the results, the anticipated dimensions for a batch injection are shown in Table 4. Table 3. Summary of Fracture Dimensions at the End of Injection Total Fracture Upper Lower Maximum EOJ9 Case Completion2 Zone3 Rate Injection Volume4 Half- Height' Heighe Well bore Net (BPM) Fluid LengthS Width Pressure (bbl) (ft) (ft) (ft) (inches)8 (psi) 1a All 2.5 9.5 ppg slurry 1,000 Upper 46 16 15 0.029 105 Shale 0 0 0 0.000 0 Lower 440 33 55 0.103 156 1b Lower Lower 2.5 9.5 ppg slurry 1,000 453 33 55 0.104 158 1c Upper Upper 2.5 9.5 ppg slurry 1,000 374 86 33 0.088 126 1d Shale Shale 2.5 9.5 ppg slurry 1,000 348 112 17 0.067 70 1e All 2.5 9.5 ppg slurry 2,500 Upper 103 21 21 0.040 117 Shale 0 0 0 0.000 0 Lower 650 34 56 0.114 168 1f Lower Lower 2.5 9.5 ppg slurry 2,500 688 34 56 0.117 172 19 Upper Upper 2.5 9.5 ppg slurry 2,500 558 87 35 0.100 134 1h Shale Shale 2.5 9.5 ppg slurry 2,500 529 113 17 0.076 78 . 2 This designates which zone is open. The upper zone would be perforated. The Lower Sand will tentatively be barefoot. Perforations are also potentially open in the shale (above the shoe and below the perforations in the Upper Sand). 3 Designates zone where fracture growth occurs. 4 Excluding displacement volume (spearhead and flush). 5 Fracture half-length is the length from the well bore to the tip of one wing of an assumed symmetrical fracture (i.e., the modeling presumes that two identical fracture wings grow diagonally away from the well bore in the direction of the maximum horizontal principal stress. 6 Designates the vertical upwards growth at the well bore from the center of the specified zone. 7 Designates the vertical downwards growth at the well bore from the center of the specified zone. S Maximum well bore width is the maximum fracture width at any position along the well bore. 9 EOJ (end of job) implies after flush, at shut-in. Net pressure is the difference between the sandface injection pressure and the in-situ stress at the mid-depth of the completed zone. . Total Fracture Upper Lower Maximum EOJ9 Case Completion2 Zone3 Rate Injection Volume4 Half- Height' Heighe Well bore Net (BPM) Fluid LengthS Width Pressure (bbl) (ft) (ft) (ft) (inches)8 (psi) 2a All 4 9.5 ppg slurry 1,000 Upper 91 21 21 0.042 121 Shale 0 0 0 0.000 0 Lower 523 34 56 0.118 172 2b Lower Lower 4 9.5 ppg slurry 1,000 554 34 57 0.121 176 2c Upper Upper 4 9.5 ppg slurry 1,000 451 87 36 0.104 137 2d Shale Shale 4 9.5 ppg slurry 1,000 424 113 17 0.078 81 2e All 4 9.5 ppg slurry 2,500 Upper 152 23 22 0.051 135 Shale 0 0 0 0.000 0 Lower 782 35 58 0.132 187 2f Lower Lower 4 9.5 ppg slurry 2,500 836 35 58 0.136 192 2g Upper Upper 4 9.5 ppg slurry 2,500 681 88 38 0.118 147 2h Shale Shale 4 9.5 ppg slurry 2,500 626 117 18 0.088 88 3a All 2.5 10.1 ppg slurry 1,000 Upper 93 31 30 0.071 158 Shale 0 0 0 0.000 0 Lower 327 43 63 0.167 214 3b Lower Lower 2.5 10.1 ppg slurry 1,000 346 47 66 0.176 218 3c Upper Upper 2.5 10.1 ppg slurry 1,000 320 94 40 0.152 170 3d Shale Shale 2.5 10.1 ppg slurry 1,000 304 119 19 0.112 112 3e All 2.5 10.1 ppg slurry 2,500 Upper 161 58 33 0.085 145 Shale 0 0 0 0.000 0 . . Total Fracture Upper Lower Maximum EOJ9 Case Completion2 Zone3 Rate Injection Volume4 Half- Height'i Heighe Well bore Net (BPM) Fluid LengthS Width Pressure (bbl) (ft) (ft) (ft) (inches)8 (psi) Lower 405 49 72 0.165 201 3f Lower Lower 2.5 10.1 ppg slurry 2,500 481 52 73 0.198 226 3g Upper Upper 2.5 10.1 ppg slurry 2,500 476 96 41 0.174 183 3h Shale Shale 2.5 10.1 ppg slurry 2,500 449 120 24 0.132 126 4a All 4 10.1 ppg slurry 1,000 Lower 110 38 33 0.083 166 Shale 0 0 0 0.000 0 Lower 347 50 72 0.191 224 4b Lower Lower 4 10.1 ppg slurry 1,000 384 52 73 0.203 231 4c Upper Upper 4 10.1 ppg slurry 1,000 376 96 41 0.178 187 4d Shale Shale 4 10.1 ppg slurry 1,000 353 120 24 0.135 129 4e All 4 10.1 ppg slurry 2,500 Lower 293 89 39 0.130 157 Shale 0 0 0 0.000 0 Lower 349 50 72 0.180 215 4f Lower Lower 4 10.1 ppg slurry 2,500 531 62 73 0.228 239 4g Upper Upper 4 10.1 ppg slurry 2,500 565 98 43 0.204 203 4h Shale Shale 4 10.1 ppg slurry 2,500 980 128 97 0.258 128 . . . . Table 4. Average Fracture Dimensions (vary according to how the well is completed) Scenario Expected Maximum Volume Volume 1,000 bbl of 2500 bbl of Slurry Slurry Fracture Half-Length (ft) [approximate] 440 550-700 Fracture Total Height (up and down) (ft) [approximate] 120 130 Fracture Width [inches, approximate] 0.1 0.11 Fracture Half-Length (ft) [approximate] 550 700-830 Fracture Total Height (up and down) (ft) [approximate] 125 130 Fracture Width [inches, approximate] 0.12 0.14 Fracture Half-Length (ft) [approximate] 350 480 Fracture Total Height (up and down) (ft) [approximate] 100 160 Fracture Width [inches, approximate] 0.17 0.18 Fracture Half-Length (ft) [approximate] 380 570-980 Fracture Total Height (up and down) (ft) [approximate] 140 140-230 Fracture Width [inches, approximate] 0.2 0.22-0.24 . . APPENDIX A INPUT PARAMETERS . . A.l. Well Information: Currently considerations for completion are: "...the lower half of the zone being completed as open hole with the possibility of perforating the upper part as needed." 10 "The disposal well be a straight hole with casing set in the middle of the Torok with an open hole completion in the lower half. The upper part can be perforated if needed. Most probably the well will fill up with solids except for a short interval below the shoe and injection will be into the middle of the Torok. Tubing will be 4.5 inch so friction losses will be minimal." The completions considered are shown in Table A-1 and Figure A-1. Table A-l. Perforated and Openhole Sections Measured Depth of Zone Depth of Comments Perforations Perforations (feet RKB) (feet TVD RKB) 5009.5-5105.5 1 5009.5-5105.5 Perforations 5164.5-5269 2 5164.5-5269 Barefoot Another situation considered was where the intermediate shale was perforated above the shoe and below the shots in the Upper Sand. A.2 Survey Information: The planned injector is straight hole. A.3 Stress Information Figure A-2 shows a type log (ARCa Kalubik #1). "The intended disposal zone ... is the Middle Cretaceous Albian-aged Torok Sand. The Torok was deposited within the Hue Shale as a deep water slope fan system. It consists of thin-bedded to laminated very fine to fine-grained sands ... between 200 and 300 feet in thickness."l "... the Torok dips regionally to the east and is somewhat broken up by small down-to-the-east normal faults." 1 Based on this alone, one would suspect that the minimum horizontal stress is directed normal to the faults. If a disposal domain develops it will be skewed in the direction normal to the minimum horizontal principal stress. 10 E-mail personal communication from D. Andrews A-I. A 0.25 0.50 50 150 100 Gamma is If the barefoot section 4900 4900 DPHI - NPHI 4950 5000 5050 5000 5100 5050 5150 5200 5100 5250 5300 5150 5350 5400 5200 5450 5250 5500 5550 5300 5600 -50 Gamma A"2. NPHI DPHI of and ray for Kalubik #1. . . "A big case would need to be looked at - volume to be up to 2,500 barrels. 10 Volume estimates are provided in Appendix B. From the available estimates, two different batch sizes were considered (1,000 and 2,500 bbl). A.5. Fluid Loss Properties The permeability was estimated using available core analysis data (Figure A-3) where the relationship with porosity is: 11 k (md) = ç x 0.0014e42.533ø(fraclion) The coefficient ç in the equation above was imposed so that the average permeability in the Upper and Lower Torok sands would be approximately 10 md.12 Uncorrected logging predictions using this formula underestimated the zone's anticipated permeability and this correction was required. Figure A-4 shows the inferred permeability. To be conservative, spurt loss (instantaneous loss in fluid when new fracture surface is created) was taken as being zero. The wall building fluid loss coefficient was estimated as follows (analog situations) Cw = 0.0019610g10k + 0.00004 ft/minute1/2 Fluid loss coefficients are shown in Figure A-5. A.6. Mechanical Properties and Stress Synthesis Laboratory values for Young's Modulus were available. The available data are shown in Figure A-6 and Table A-2. The laboratory data were used to calibrate the raw modulus predictions derived from compressional and shear wave slownesses (Figure A-7). Moduli were also estimated from inferences of the shear wave slowness (Figure A- 8). The correction from dynamic (logging) to static (for simulation) values was based on a crossplot of laboratory measurements (Figure A-9). Poisson's ratio is shown in Figure A-10. The stresses were then estimated using Poisson's ratio, bulk density, moduli and local information (values at Alpine) [refer to Figure A-11] 11 PowerPoint slides were provided by Pioneer Natural Resources --- Ooorguk Perm Data.PPT (November 14, 2006). 12 Teleconference with D. Andrews and K. Schmidt. Mechanical Data Grain Static Poisson' s s A-3. based on 0.1 4900 100 1000 5000 5100 5200 5300 o Gamma 5100 5200 5300 A~5. and increased to Torok sands. Loss Gamma 75 1 4900 5100 5200 5300 150 coefficient with a an average A~6, 2.80 2.60 2.40 ~ .¡;; Cb 2.20 \J) ::) ~ 2.00 o ¿ \J) -01 c: ::) o >- u :¡:; 13 V"J A~1, 1.00 1.20 for corrected to moc::h.dus meëlsurement5 hëld been mëlde in the here. Those vëltues are summarized in Table A~2, the 0.8022x + 0.1157 R2 '" 0.4548 @ \1\1 1.40 1.60 2.80 3.00 2.40 2.60 1.80 Dynamic Young's Modulus psi) of vëllues of The fëlW sœtk: vëllues modulus to values the linear were 100 Wave Gamma 300 400 4000 4250 4250 4500 4750 5000 5000 5250 5500 5750 5750 6000 6250 6250 6500 100 200 300 400 Gamma A-8. shear wave slowness. 4.0E+06 6.0E+06 8.0E+06 3750 4250 4250 4500 4750 5000 5000 5250 5750 5750 6000 6000 6250 6500 6500 0 100 200 300 Gamma A-9, and p- 4000 5750 -100 A-l0. Poisson's ratio. 0.25 3500 3500 Pressure Horizonta! 3750 3750 4000 4000 4250 4250 4500 4500 4750 4750 5000 5000 5250 5250 5500 5500 5750 5750 6000 6000 6250 6250 6500 6500 400 0 100 200 Gamma A~ll. pressure The was the zones 300 feet at . . APPENDIX B WASTE STREAM (After PNR, January 2006) . - The following is based on a Pioneer Natural Resources Alaska internal document provided to develop input for the simulations. Forecasted Drilling Wastes Oooguruk Project (1-13-06) · Forecasted drilling wastes are based on the 41 well directional development program provided by Sperry Sun (1-9-06) using the 12 1f4, 8 1/2, 6 1/8 bit schedule provided by Pioneer. The ... average development well will have the following profile. . 3712 feet MD 6980 feet M D 6120 feet MD 16 812 feet MD 689 310 feet 52 019 barrels · Several cases were calculated to investigate the range of waste volumes that might have to be dealt with. · Waste volumes were investigated based on both general North Slope experience and on the very similar ongoing Alpine operations which includes recovery of oil base mud used in the production hole. · It is estimated that development drilling will generate the following volumes. The "cuttings" content in the expected case would be 10.2% of the total fluids injected (52,019/500,000). The rest of the barrels would be mud and dilution fluids used as carrier in the injected slurry; plus water to clean equipment and flush water to clear the wellbore. Some details are included in the following table. Total Drilling Mud/ Cuttings/Slurry/ Fluids Injected (Barrels) Averaae Well Total 41 Wells EXDected Case 13.220 500 000 Minimum Case 12.000 450.000 Maximum Case 15,000 550,000 · If the bit/borehole/casing program changes, these numbers will need to be altered to fit the situation. · If the Torok disposal well has 580 barrels of borehole volume, and it is assumed 1160 barrels of mud/cuttings go directly to the pit (dry cuttings), . . followed byl150 Bbls mud from surface tanks, (750 surface hole change- out and 400 during completion), and 300 Bbls cement/other, this generates 2600 barrels of storage that could be required before the disposal well can be used. Expected Injection Well Disposal Case: Average Total 41 Well Wells Slurry: (mud/cuttings/dilution for injection). Does 9000 ^'369,000 not assume any surface gravel recovery. (Cuttings 14% of stream). Surface Hole 3000 Int Hole 4500 Prod Hole 1500 Well Flush Water/Rig Wash/Freeze Protection 3500 ^'103,OOO Cement and Rinsates 120 ^'4,900 Completion Fluids, etc. 600 ^' 24 600 Totals 13,220 ^'500,OOO Minimum Iniection Case: 12,000 ^'450,000 Maximum Injection Cases: ^' 550,000 Notes: 1. The variation between cases is a function of dilution, well flushing, and freeze protection activities. 2. No recovery of surface gravel assumed. 3. Recovery of OBM in production hole assumed at 60% per MI Swaco. · APPENDIX C RESULTS e 5280 3000 3500 4000 Stress 500 Stress ¡¡¡:¡ 6II! C-2. This for Case 1b lower into aU barefoot C=3. This is for Case 1c sand. /"""-. <!:: '../ "'" = "'" Stress (PSi) Stress C=4. is the for Case ld the above g Ci > bS S2!!!J :m:J 6m into all ~hale above the 2 '-" Ci > b Q Width (in.) Em jfiJ C~6. Thi~ is for Case lower at an barefoot C-1. This for Case sand. Stress This is the in for Case 2«:: sand. into upper Torok srn C-12. This is the in for Case above the into into all three zones shale above the g Q > ~ :mJ " Wídth eín) æ¡ "'" Length eft) shut- into aU into into ¡fi' ,-". a >- b 51tll S1B!! g a >- b :mJ a Width (in) ;m C-19. in for Case 3t: sand. C¡ :> ¡- 21m 21m <mJ Stn~ss (psi) into :mJ :m:¡ Stress Stress (psi) n ì{ilidth (in.) E :m Length (ft) œ &IJ :m:J into g w :>- f- C~23. This is the for Case sand. into """I 51!]] 5' = " "Vidth (in) Length (ft) into after flush 10.1 PH the in for Case 4a zones g Ç¡ :> ¡- Stress c > b C-27. This is in for Case 4c sand. c > b Width Contours = 3m Stress 3m <W &D &D Stress (psi) into g Q >- r :;m¡ into into #3 RE: Public Hearing on Oooguruk Disposal well . . Thanks for your help Jim - John Hellen did give a call. We are all set. Temple From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, April 30, 20073:11 PM To: Temple Davidson Subject: Re: Public Hearing on Oooguruk Disposal well you'll be getting a call rrom Pioneer (John Hellen) Jim Regg AOGCC Temple Davidson wrote: Ah-ha! That makes sense. I found out because I am on Jodie's list. As far as I know, Pioneer didn't notify DNR directly. Thanks, Temple From: James Regg [mailto:jim reqq@admin.state.ak.us] Sent: Monday, April 30, 2007 12:38 PM To: Temple Davidson Subject: Re: Public Hearing on Oooguruk Disposal well We received no comments so the hearing was vacated. I do have a question you may be able to answer, however. Did DNR recieve formal notification from Pioneer regarding the application, and if so, when? Jim Regg AOGCC Temple Davidson wrote: Hi Jim, Cammy suggested I get ahold of you - tomorrow is the Disposal Injection Order public hearing for Oooguruk, which is one of my units. Last I heard, the hearing was still on, I am wondering if there was public comment? Also, I hadn't planned on attending, since I had assumed there probably would not be a hearing. But perhaps I should? Any info you have would be greatly appreciated, ] of2 5/1/2007 9:55 AM RE: Public Hearing on Oooguruk Disposal well . . Thank you, Temple Ms. Temple Davidson Petroleum Land Manager State of Alaska Department of Natural Resources Division of Oil and Gas Suite 800 550 West 7th Avenue Anchorage, Alaska 99501 (907) 269-8784 20f2 5/1/2007 9:55 AM #2 STATE OF ALASKA . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. ADVERTISING ORDER 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-02714024 F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M 907-793-1238 Ceresa Tolle PHONE March 20 2007 PCN ¿ Anchorage Daily News PO Box 149001 Anchorage, AK 99514 March 25, 2007 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal~ o Display Classified DOther (Specify) SEE ATTACHED AOGCC, 333 W. 7th Ave., Suite 100 Anchorage. AK 99501 AMOUNT DATE ARD 02910 4 ~IN .ð.MnIINT ~v f"'.f"'. Pr.M 1 05 02140100 2 3 If"'. .ð.f"'.f"'.T ~v NMR DIST UQ 73451 DIVISION APPROVAL: 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. 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-02714024 R o M AOGCC 333 West ih Avenue. Suite 100 A n('hnr~(1p A K QQ,\O 1 907-793-1238 AGENCY CONTACT DATE OF A.O. T o Anchorage Daily News PO Box 149001 Anchorage, AK 99514 March 25, 2007 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 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 sworn, according 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 publication appearing on the _ 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 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER Legal Ad for Publication on March 25, 2007 . . Please publish on March 25, 2007. If you have any questions my number is 793-1238. Thank you Ceresa Content-Type: application/msword Content-Encoding: base64 Content-Type: application/octet -stream Public Hearing May 0107.pdf.lnk Content-Encoding: base64 I of 1 3/20/2007 9:33 AM STATE OF ALASKA . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. ADVERTISING ORDER 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-02714025 F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M 907-793-1238 Ceresa Tolle PHONE March 20 2007 PCN DATES ADVERTISEMENT REQUIRED: T The Arctic Sounder o 301 Calista Court, Suite B Anchorage, AK 99518 March 29,2007 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal[g D Display Classified DOther (Specify) SEE ATTACHED AOGCC, 333 W. 7th Ave., Suite 100 Anchoralle. AK 99.'iOl AMOUNT DATE ARD 02910 4 r::IN .ð.MOIINT ~v r:.r:. P~M 05 02140100 2 3 Ir:. .ð.r:.r:.T r::v NMR OIST un 73451 DIVISION APPROVAL: 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM . . ALASKA NEWSPAPERS INC. 301 CALISTA COURT, SUITE B ANCHORAGE, ALASKA 99518-3028 ~(907) 272-9830 * ~(907) 272-9512 AK OIL & GAS CONSERVATION COMMITTEE JODY COLOMIE 33 W 7TH AVE, STE 100 ANCHORAGE, AK 99501 Date: March 29, 2007 CASE/PO/AIO: 2714025 INVOICE(S) : 030700320016 PAPER: ARCTIC SOUNDER 't ~~^ ~ ~. \..~ ~ ~ ,~ cf r:P ~ ~ ~ & ,'^ I?~ 'ò. ~ V ~ ~ ? ~ .~ ~ ,. ~. ~-? AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA, STATE OF ALASKA, THIRD DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED SHANNON MOONEY WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT SHE IS THE BILLING CLERK FOR: THE ARCTIC SOUNDER, PUBLISHED AT ANCHORAGE IN SAID DIVISION THREE AND STATE OF ALASKA AND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON 3/29/2007 AND THEREAFTER FOR A TOTAL OF 1. CONSECUTIVE ISSUE(S), THE LAST PUBLICATION APPEARING ON 3/29/2007, AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE CHARGED TO PRIVATE INDIVIDUALS. ç-~~:;::--;? ~¿-~~ SHANNON MOONEY BILLING CLERK, ALASKA NEWSPAPERS "~~"'~\fÁ~'ltl, ¿:- ,Cb ....... ~.L\ I, ::" ~ q,"- .... ~r I, .: ~ - AR'" 'I. :: ;~.. ~\.,O;'\' 1 '. ~ ,,"''V: ,_. ':.~ I- :: ....: 0 ~ ~ . tfIIP ç, .1.\1:; ~ ;. : PUr.t\.'\ 5= . ~ I.". '"' ""'''fJ' ~ (> '..\P~ ;t.'- :' '. I,r,~ Q'?,>",,":¡f"1¡ Of ~~'~\1.~CJ I. J '. ·'''/4\ . '·..Ii " ..... ¡lli,~fa('¡ 5)(\)\1~' ..;"..."-' "1\\\""""......" SUBSCRIBED AND SWORN TO ME ON March 29. 2007 ~>¡f,~ rfÆ,- CHRISTINA RITTER MY COMMISSION EXPIRES ON MARCH 24, 2009 Thursduy, March 29, 2007 --._-_.-..._----~. - Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order for Oooguruk Unit Development Pioneer Natural Resources Alaska, Irie. ("Pioneer") by feller dated March ·14, 2007, has applied for a Disposallnjec!ion Order under 20 AAC 25.252, authorizing disposal of Class 1/ drilling and production wastes into the Torok said within the Oooguruk Unit. Pioneer has installed a drillsite in State of Alaska waters approximately 6 miles offshore in the Beaufort Sea, northwest of the Colvífle River detta. The application includes primary and alternate Class II disposal wells. Pioneer's application is a con- tingency in the event the Environmental Protection Agency does not issue a Class per- mit for non-hazardous waste injection prior to September 2007 commencement of Oooguruk development drilling. The proposed Oooguruk development area is located within portions of T13N-R7E, T13N-R8E, T14N-R7E, andT14N- R8E, Umiat Meridian; and the receiving zone for this well is at an approximate depth of 5000 feet below sea level. The Commission has tentatively scheduled a public hearing on this application for May 1, 2007 at 9:00 am at 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 The Arctic Sounder LEGAL NOTICES pm on April 16, 2007. . .. . If a request for a hearing is not timely filed, the Commission will consider the Issuance of an order without a' hearing. To learn If the Commission will hold Ihe public hearing, please call 793-1221 after April 18, 2007. . In addition, a person may submit written com- ments regarding this application to t~e Alaska Oil and Gas Conservation Commission at 333 West ¡fh Avenue, Suite 100, Anchorage,Alaska 99501. Written comments must be received no later than 4:30 pm on April 6, 2007 except that if the Commission decides to hold a pubhc hear- ing written protest or comments must be rec~ived no later than the conclusion of the May 1 2007 hearing. If'you are a person with a.disability who may need special modifications In order to comment or to attend the public hea:ing, pl~ase contact the Commission's Special Assistant Jody Colombie at 793-1221 before April 25, 2007. John K. Norman Chairman Published: March 29, 2007 AO# 02714025 (3116313/29) ..- '..... ___......, '....."T'"..- Thursday, March 29, 2007 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order for Oooguruk Unit Development Pioneer Natural Resources Alaska, Inc. ("Pioneer") by letter dated March 14, 2007, has applied for a Disposal Injection Order under 20 AAC 25.252, authorizing disposal of Class II drilling and production wastes into the Torok said within the Oooguruk Unit. Pioneer has installed a drillsite in State of Alaska waters approximately 6 miles offshore in the Beaufort Sea, northwest of the Colville River delta. The application includes primary and alternate Class II disposal wells. Pioneer's application is a con- tingency in the event the Environmental Protection Agency does not issue a Class I per- mit for non -hazardous waste injection prior to September 2007 commencement of Oooguruk development drilling. The proposed Oooguruk development area is located within portions of T13N-R7E,T13N-R8E,T14N-R7E,and T14N- RSE, Umiat Meridian; and the receiving zone for this well is at an approximate depth of 5000 feet below sea level. The Commission has tentatively scheduled a public hearing on this application for May 1, 2007 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A oerson may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on April 16, 2007. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after April 18, 2007. In addition, a person may submit written com- ments -regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Written commentsmust u t be received xcept th o later than 4:30 pm on April if the Commission decides to hold a public hear- ing, written protest or comments must be received no later than the conclusion of the May 1, 2007 hearing. If you are a person with a disability who may need special modifications in order to commentt or to attend the public hearing, please the Commissi0n,s Special Assistant y Colomb e at 793-1221 before April 25, 2007.. John K. Norman Chairman Published: March 29, 2007 AO# 02714025 (311631 3/29) The Arctic Sounder STATE OF ALASKA ADVERTISING ORDER . NOTICE TO PUBLISHER . ADVERTISING ORDER NO. 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-02714025 F AOGCC 333 West 7th Avenue. Suite 100 An~h()nH"p AK QQ;;¡Ol 907-793-1238 AGENCY CONTACT DATE OF A.O. R o M DATES ADVERTISEMENT REQUIRED: T o The Arctic Sounder 301 Calista Court, Suite B Anchorage, AK 99518 March 29,2007 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: 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 sworn, according 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 publication appearing on the _ 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 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER . . Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Disposal Injection Order for Oooguruk Unit Development Pioneer Natural Resources Alaska, Inc. ("Pioneer") by letter dated March 14, 2007, has applied for a Disposal Injection Order under 20 AAC 25.252, authorizing disposal of Class II drilling and production wastes into the Torok sand within the Oooguruk Unit. Pioneer has installed a drill site in State of Alaska waters approximately 6 miles offshore in the Beaufort Sea, northwest of the Colville River delta. The application includes primary and alternate Class II disposal wells. Pioneer's application is a contingency in the event the Environmental Protection Agency does not issue a Class I permit for non-hazardous waste injection prior to September 2007 commencement of Oooguruk development drilling. The proposed Oooguruk development area is located within portions of T13N-R7E, T13N-R8E, T14N-R7E, and T14N-R8E, Umiat Meridian; and the receiving zone for this well is at an approximate depth of 5000 feet below sea level. The Commission has tentatively scheduled a public hearing on this application for May 1, 2007 at 9:00 am at 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 April 16,2007. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after April 18, 2007. In addition, a person may submit written comments regarding this application to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Written comments must be received no later than 4:30 pm on April 6, 2007 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 May 1,2007 hearing. If you are a person with a disability who may need special modifications in order to comment or to attend the public hearing, pleas ntact the Commission's Special Assistant Jody Colombie at 793-1221 before April 25, 200 . Published Date: Anchorage Daily News March 25, 2007 AO# 02714024 Published Date: The Arctic Sounder March 29,2007 AO# 02714025 Public Hearing Notice for Publication . . Please print in the Arctic Sounder March 29, 2007. If you have any questions my number is 793-1238. Thank you Ceresa Content-Type: application/pdf DOC070319-001.pdf . Content-Encodmg: base64 Content-Type: application/msword AO-02714025.doc· Content-Encoding: base64 I of I 3/20/2007 9:33 AM Public Hearing Notice May 1, 2007 . . Thanks Bren! ¡ . Content-Type: applicationlpdf DOC070319-001.pdf Content-Encoding: base64 1 of 1 3/20/2007 9:44 AM Public Hearing Notice May 1,2007 . . Subject: Public Hearing Notice May 1, 2007 From: Jody Colombie <jody _ colombie@admin.state.ak.us> Date: Tue, 20 Mar 200709:55:52 -0800 To: undisclosed-recipients:; BCC: Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, staneIg <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, trmjr 1 <trmjr 1 @ao1.com>, jdarlington <jdarlington@forestoi1.com>, nelson <knelson@petroleumnews.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 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.Schultz@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>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobi1.com>, Mark Kovac <yesno1@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.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>, buonoje <buonoje@bp.com>, Mark Hanley <mark _hanley@anadarko.com>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@alaskadc.org>, 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@rkindustrial.com>, ghammons <ghammons@ao1.com>, rmcleart <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@ao1.com>, Brian Gillespie <itbmg@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>, 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>, jack newell <jack.newell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, n1617@conocophillips.com, 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 <sheffield@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>, Jeff <smetankaj@unocal.com>, Gary Rogers <gary_rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <k1yons@otsint1.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Mike Mason lof2 3/20/2007 9:56 AM Public Hearing Notice May 1,2007 . . <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoi1.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve _ davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com>, Deanna Gamble <dgamble@kakivik.com>, James B Regg <jim_regg@admin.state.ak.us>, Catherine P Foerster <cathy_foerstet@admin.state.ak.us>, Bob <Bob@fairweather.com>, gregory micallef <micallef@c1earwire.net>, Laura Silliphant <laura_silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobi1.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve_moothart@dnr.state.ak.us>, Anna RafI <anna.raff@dowjones.com>, Cliff Posey <cliff@posey.org>, Paul Bloom <paul_ bloom@ml.com>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson <temple ~ davidson@dnr.state.ak.us>, Walter Featherly <WFeatherly@PattonBoggs.com>, Tricia Waggoner <twaggoner@nrginc.com>, Mike Stockinger <Mike.Stockinger@anadarko.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 <jimwinegarner@brooksrangepetro.com>, Matt Rader <matt_rader@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@intemational.gc.ca>, Cary Carrigan <cary@kfqd.com>, Sonja Frankllin <sftanklin6@bloomberg.net> Jody Colombie <iody colombie(á¿admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration Content-Type: application/pdf OoogurukDIO 050107.pdf C E d" b 64 ontent- nco IBg: ase 20f2 3/20/2007 9:56 AM #1 . . R.ECE\VED MÞ,R 1 5 2007 ... ~ commission t.\\aska Oil &. Gas Cons. Anchorage PIONEER March 14, 2007 NATURAL RESOURCES ALASKA. INC. Commissioner John Nonnan Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Application for Disposal Injection Order Oooguruk Unit Development Project Beaufort Sea, North Slope Basin Dear Commissioner Norman: Pioneer Natural Resources Alaska, Inc. submits for your review and action, this application for a disposal injection order to authorize injection of Resource Conservation and Recovery Act (RCRA) exempt drilling and production wastes into strata within the Oooguruk Unit boundary. A Class II disposal injection order is requested to provide a needed contingency for the Oooguruk Development Project in the unlikely event that the EP A does not issue a Class I well penn it prior to commencement of drilling operations. Development drilling on the offshore development pad is planned to begin in September, 2007 and the critical disposal well will be the first well drilled. A ruling is requested that will allow for appropriate planning and other activities to occur before that time. An injection interval bounded by major shales has been identified between 5000 feet and 5250 feet. It is envisioned that drill cuttings, mud, and other RCRA exempt wastes will be pumped into the Torok Formation in a dedicated grind and inject disposal well. Other volumes of dirty fluids from drilling and production operations will have a low solids content. The application was prepared in accordance with Title 20, Chapter 25.252. It provides data and documentation to substantiate that all the aquifers below the top of the confining zone at approximately 4,000 feet are not underground sources of drinking water (USDW). (The EP A ruled in their letter of August 18, 2006 that no Underground Source of Drinking Water exists). The application also substantiates that that fracturing of the Torok Fonnation will not penetrate the arresting shales or the confining zones. Inquiries regarding clarification may be directed to John Hellén at 907/343-2102. lAm e~7! ¡J¡J . "ß~all perations Manager - Alaska Enclosure: Application Document 700 G STREET. STE. 600 . ANCHORAGE. ALASKA 99501 . MAIN: (907) 277-2700 . . RECEIVED MAR 1 5 2007 AI.ska Oil & Gas Cons. Commission Anchorage PIONEER Natural Resources Alaska, Inc. Oooguruk Development Project Application for Disposal Injection Order Beaufort Sea, North Slope Basin 20 MC 25.252 Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 March 2007 . Oooguruk Development Project . Application for Disposal Injection Order Table of Contents Section Pa2e Introduction.................................................................................................................. ........1 Well Locations 20 AAC 25.252 (c) 1......................................................2 Surface Owners and Operations 20 AAC 25.252 (c) 2 & 3...............................................3 Geologic Details 20 AAC 25.252 (c) 4......................................................4 Well Logs 20 AAC 25.252 (c) 5......................................................6 Well Construction 20 AAC 25.252 (c) 6......................................................7 Waste Types and Volumes 20 AAC 25.252 (c) 7....................................................12 Injection Pressures 20 AAC 25.252 (c) 8....................................................13 Waste Confinement 20 AAC 25.252 (c) 9....................................................14 Formation Water Salinity 20 AAC 25.252 (c) 10 & 11.........................................16 Wells Within the AOR 20 AAC 25.252 (c) 12..................................................18 Well Mechanical Integrity 20 AAC 25.252 (d) & (e).............................................19 Exhibit 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 Project Location Map Unit Boundary with Development Plan Unit Boundary With Tract Ownerships Type Log - Kalubik 1 Cross Section Well Location Map Geologic Cross Section Structure Map - Torok Sand Structure Map - Top Arresting Zone Structure Map - Top Confining Zone Disposal Well Proposed Completion (DW-1) Wellhead Valving (2 Drawings) Disposal Well Sidetrack Contingency Proposed Completion (DW-2) Torok Completion Options - Kalubik 1 Torok Fracture Modeling for Oooguruk Waste Injection Typical Fracture Profiles Plume Area Well Locations - Salinity Calculation Points Salinity Calculations (18A and 18B) US Environmental Protection Letter, No USDW Ruling Pioneer Natural Resources Page ii March 2007 . . Application for Disposal Injection Order Oooguruk Development Project Introduction Pioneer installed the Oooguruk Drillsite (ODS) in State of Alaska waters approximately 5.7 miles offshore in the Beaufort Sea, near the mouth of the Colville River. The drill site is in four to six feet of water and will serve as a drilling and production platform for approximately 40 wells. An additional eight slots are available for future development. Produced fluids, water for injection, gas for gas injection and gas lift and Arctic heating fuel will be transported between the ODS and the Oooguruk Tie-in Pad (OTP) in a buried subsea flowline bundle. The location is shown in Exhibit 1. The subsea connecting flowlines transition to an above-ground flowline onshore, and finally terminate in an existing Kuparuk River Unit (KRU) common line. The KRU facility is operated by ConocoPhillips Alaska Inc. KRU will process and separate the Oooguruk oil, water, and gas for sales and disposal. Fuel gas will be provided by the KRU. The fuel gas line is designed to transport gas to the OTP to fuel the turbine generators and produce electricity for the ODS. Electricity from the turbines will be transmitted to the ODS through electric cables installed adjacent to the subsea flowline bundle. Electricity from the OTP will provide the primary source of power for the drilling rig and the production facilities at the ODS. The drilling rig on the drill site has three diesel engine/generator sets capable of producing 3300 KW of power, the production facility has a 2.2 Megawatt diesel/generator set and the camp will be equipped with two 500 KW diesel/generator sets to provide power in the absence or loss of electric power from the turbine generators at the OTP. An arctic heating fuel line will be included in the subsea flowline bundle for transporting arctic heating fuel from two 600 barrel fuel tanks located at the OTP to two 600 barrel tanks located at the ODS. Some of the development wells will be water and gas injectors. High pressure water and gas for these injectors will also be provided by the KRU. The high pressure water will be transported offshore in the subsea flowline bundle. Likewise a line providing gas for the injection wells and gas lift for the producing wells will be transported to the ODS in the subsea flowline bundle. The development plan involves wells drilled horizontally in the Nuiqsut Formation and the Kuparuk "C-sand" as shown in Exhibit 2. Drilling operations are projected to begin in September, 2007. Drilling operations for the 40 wells will last approximately three years. The ODS camp can accommodate 76 people and will be fully used during the construction and drilling phase. Afterwards, during the production phase, it is planned that the drill site will be basically unmanned except when the rig is intermittently active or maintenance is going on. Pioneer Natural Resources Page 1 March 2007 · Oooguruk Development Project APPliC. for Disposal Injection Order Well Locations 20 AAC 25.252 (c) 1 Oil production will come from the Nuiqsut oil reservoir at 6300 +/- feet and from the Kuparuk "C-sand" at 6100 +/- feet. These reservoirs are separated from the Torok disposal interval at approximately 5000 feet by a dense shale interval. The grind and inject disposal well, DW-1, is planned as a straight hole vertically below the drillsite (latitude 70.4958 N, longitude 150.2467 W). Pioneer is also planning a second disposal well, DW-2, at an alternate location to the east as a contingency should mechanical problems develop in DW-l. The approximate bottom hole location of DW-2 is latitude 70.4923 N, longitude 150.2308 W, although therè may be a need to shift the location of DW-2 based on drilling results as things develop. These locations are shown in more detail on following exhibits. Pioneer Natural Resources Page 2 March 2007 Oooguruk Development let APPli.n for Disposal Injection Order Surface Owners and Operators 20 AAC 252 (c) 2 & 3 The Unit boundary and surface owners are shown in Exhibit 3. There are no adjacent operators within 1,4 mile. Surface Issues: The State of Alaska Department of Natural Resources Division of Mining, Land, and Water 550 West 7th Avenue, Suite 1070 Anchorage, AK 99501 Subsurface Issues: The State of Alaska Division of Natural Resources Commissioner, Department of Natural Resources 400 Willoughby Avenue, 5th Floor Juneau, AK 99801-1796 Pioneer Natural Resources Page 3 March 2007 Oooguruk Development pIt APPlica!for Disposal Injection Order Geolosdc Details 20 AAC 252 (c) 4 Deposition/Litholo2Y IStrati2raphy The intended disposal zone for disposal of Pioneer's development and production wastes is the Middle Cretaceous Albian-aged Torok Sand. A deepwater base-of-slope fan system, the Torok was deposited within the Albian to Cenomanian-aged marine Hue Shale as thin-bedded distal levees, overbank deposits, and occasional small channels or crevasse splays. Litho-stratigraphic log markers were used to delineate the disposal interval and are illustrated on the Arco Kalubik #1 type log (Exhibit 4). The correlative nature of the markers is demonstrated by the cross section line of Exhibit 5 which shows the location of the two proposed disposal wells and Exhibit 6 which illustrates the continuity of the geology. The Arco Ka1ubik #1 was chosen as the type log because of its relatively modem and complete log suite and close proximity to the disposal location. The fans comprising the Torok were likely sourced by turbidity flows originating from the west and traveling by west-east trending canyons cutting a north-south oriented shelf- slope break. Distal levee deposits are the dominant depositional facies, consisting of thin- bedded (1-12") to laminated (less than 5mm) very fine to fine-grained litharenitic sands inter-bedded with siltstones and basinal mudstones. Deposition is interpreted to have occurred as low density turbidity flows and hemipelagic sedimentation. Occasional thin (less than 10') channels or proxima11evee deposits suggest the presence of nearby larger channels or levees, but these have not been encountered by any well in the area. To the west (updip and upslope), the Torok grades into mudstones and siltstones. Iniection and Confinin2 Zones As the Exhibit 4 type log and cross sectional Exhibits 5 and 6 illustrate, the Torok Sand varies between 200 and 300 feet in thickness. The Torok structure map (Exhibit 7) is based on well data and seismic data mapping. The Torok structure map and cross section illustrate that the Torok dips regionally to the east and include small down-to-the-east normal faults to the west of the disposal location. Displacement along these faults is less than the thickness of the disposal interval, but the high mud and silt content of the interval should cause hydraulic isolation within the Torok due to shale smear. No significant faulting has been identified to the east of the proposed disposal well area. The 500-800 foot thick upper arresting zone, the 140-200 foot thick upper confining zone, and the 400-800 foot thick lower confining zone are all part of the thick 1aterally- extensive marine Hue Shale, which includes the HRZ Shale. Structure maps of the upper arresting and confining zones are shown in Exhibits 8 and 9. There are no significant Pioneer Natural Resources Page 4 March 2007 . Oooguruk Development Project . Application for Disposal Injection Order sands within the arresting or confining zones in the Oooguruk area. Structure maps on the Torok disposal interval, the upper arresting zone, and upper confining zone are very similar. Reservoir Properties Torok interval porosities average 15-20% with permeabilities of 1-70 millidarcies. The permeabilities in the levee and overbank deposits typically are less than 10 millidarcies, while the channels or crevasse splays, which contain less silt and mud, exhibit permeabilities toward the higher end of the range. The thin-bedded character of the Torok Sand likely resulted in vertical permeabilities much lower than the horizontal permeabilitiesmeasured in core. Drill stem tests (DST) or formation tests in two wells in the general area - the· Arco Kalubik #2 and the Texaco Colville Delta #3 - tested oil in the Torok. The planned disposal location is down dip and/or fault-separated from those wells, with the wet Arco Kalubik #1 located between the updip Kalubik #2 and the downdip disposal locations beneath and near the development pad. DSTs and formation tests in the Pioneer Ivik #1, Arco Kalubik #1, and Texaco Colville Delta #2 proved to be water productive. Pioneer Natural Resources Page 5 March 2007 · Oooguruk Development Project APPlica!for Disposal Injection Order Well Logs 20 AAC 252 (c) 5 Well Logs will be provided when the disposal· wells are drilled. Pioneer Natural Resources Page 6 March 2007 · Oooguruk Development Project APPIiC. for Disposal Injection Order Well Construction 20 AAC 252 (c) 6 Well DW-1 (ODS-44) will be directionally drilled vertically to a bottom hole location with departure of approximately 0 feet and to a final vertical depth of approximately 5300 feet sub sea. This section includes the construction details for well DW-l (ODS-44) as well as the projection for alternate well DW-2. All construction requirements exceed the specifications required by CFR and State of Alaska regulations. The casing-cementing program for DW-l is depicted in the schematic of Exhibit 10 and the wellhead valving in Exhibit 11. The surface hole will be logged as specified to ensure that the surface casing shoe is well bonded to the formation. This placement, plus the use of Class-G cement as the tail slurry around the casing shoe will ensure good zonal isolation up to the permafrost. A full logging program will be run in the lower hole. The long string will be cemented with an excess volume to ensure bonding. Zonal isolation will be verified by cement bond logs. Both surface casing and injection casing integrity will be verified by pressure testing. The tubing by casing annulus will be isolated above the injection interval by a packer. The annulus will be filled with corrosion inhibited sea water with a diesel cap for freeze protection. The tubing and tubing by casing annulus will be pressure tested to 3500 psi. Should the well not pressure test satisfactorily the tubing will be removed and the problem corrected. The well head assembly is shown in Exhibit 11. The wellhead, controls, and monitoring instrumentation will all be enclosed in an insulated and heated well house. Pioneer Natural Resources Page 7 March 2007 . Oooguruk Development Project . Application for Disposal Injection Order Proposed Drilline; and Completion Proe;ram: Well DW-l (ODS-44) Surface location (as-staked): ASP "X" 469826.67 & ASP "Y" 6031010.37 2385' FNL & 1172' FEL Sec 11, T13N R7E Target location: Same Target Accuracy: 200 ft Radius (+/- 200 feet) Estimated start date: September 2007 Maximum angle: o degrees Kick off depth: nla Wellbore azmith: V ertical Well Kelly bushing (KB) elevation: 56 feet above sea level Item and Depths Subsea TVD (BKB) MD (BKB) (measured depth below rig floor) 16" Conductor ±106 ±162 ±162 Base Permafrost 1485 1541 1541 9-%" Casing Shoe 2750 2806 2806 Top Confining Zone 4040 4096 4096 Base Confining Zone 4220 4276 4276 Top Injection Zone 5020 5076 5076 7" Casing Shoe 5150 5206 5206 Base of Injection Zone 5300 5356 5356 6-Ifs" Open Hole (Target) 5300 5356 5356 Pioneer Natural Resources Page 8 March 2007 . Oooguruk Development Project . Application for Disposal Injection Order Logging Program Open Hole: 12-1,4" Surface Hole: GR/RES/SP/Caliper (From TD to 500' ) 8-W' Hole: GR/RES/SP/DENS/NEUT (From TD to 9-%" shoe) Cased Hole: Cement bond log from 9-%" shoe up to 500 feet. Cement bond log from 7" shoe to top of cement. Directional survey run from total depth. Freeze Protection Plan The 4 W' x 7" annulus will be freeze protected with corrosion inhibited seawater with a diesel cap through the permafrost. Casing / Tubing Specifications ~ Size Weight Grade Connection Tension Burst Colla{Jse Surface 9-%" 40 Ib 1ft L-80 BTC 916,0001bs 5750 psi 3090 psi Inj. Csg 7" 26 Ib 1ft L-80 BTC-M 604,000 lbs 7420 psi 5410 psi Inj. Tbg 4-Y2" 12.6 Ib 1ft L-80 IBT-M 289,0001bs 8430 psi 7500 psi Cement Volumes 9-%" Surface Casing: Measured Depth: 2806 feet Basis: 12-W' x 9-%" annulus volume with 250% excess across the permafrost and 30% excess below the base of the permafrost. Total Cement Vol.: 2148 cu ft - subject to revision based on hole conditions Lead Slurry Vol.: 1766 cu ft, 425 (sx) Permafrost L at 4.15 cu ft/sx (from surface to 500 feet MD below Permafrost) Pioneer Natural Resources Page 9 March 2007 . Oooguruk Development Project APPliC! for Disposal Injection Order Top Job: 382 cu ft, 332 sx Class G cement at 1.15 cu ftlsx (from 500 feet MD below Permafrost to casing shoe) If no cement returns to surface: Pump 250 sx Permafrost L at 4.15 cu ftlsx. Tail Slurry Vol.: 7" Injection Casing: Measured Depth: 5206 feet Basis: 8-1;2" x 7" annulus volume with 30% excess 500' above the top of the confining zone. Total Cement Vol.: 333 cu ft, 285 sx Class G cement at 1.17 cu ftlsx. - subject to revision based on hole conditions. Construction Procedures · Set 16" drive pipe conductor casing at +/- 162' TVDrkb. Move in the drilling rig. Install the diverter and function test. · Directionally drill a 12-1,4" hole to the surface casing point. · Rig up and run E-line logs: GR/RES/SP/Caliper. · Run and cement the 9-%" surface casing. Install the blowout preventer (BOP) and pressure test per AOGCC regulations. · Pick up an 8-Y2" bottom hole assembly (BHA), run in the hole and c1eanout the casing to the top of the 9-%" landing collar. Test the casing to 3,500 psi for 30 minutes. POH · Run a cement bond log from the top of the landing collar to 500 feet. · Pick up an 8-1;2" bottom hole assembly (BHA) and run in the hole. Drill out the shoe, rat hole and 20' of new formation. Perform a leak off test (LOT). · Drill an 8-1;2" hole into the proposed injection interval to the intermediate casing depth. · Rig up and run E-line logs: GR/RES/SP/NEUT/DENS. · Run and cement the 7" casing from TD to 500' above the confining zone. Pioneer Natural Resources Page 10 March 2007 Oooguruk Development !ct . Application for Disposal Injection Order · Pick up a 6-YS" bottom hole assembly (BHA) and run in the hole and cIeanout the casing to the top of the 7" landing collar. Test the casing to 3500 psi for 30 minutes. POH. · Run a cement bond log from the top of the landing collar to 500' above the confining zone. · Pick up a 6-W' bottom hole assembly (BHA) and run in the hole. Drill out the shoe, rat hole and 20' of new formation. Perform a leak off test (LOT). · Drill a 6-Ys" hole through the proposed injection interval to total depth (TD). POH. · Run 4Yz" 12.6# L-80 tubing. Freeze protect annulus with corrosion inhibited seawater with diesel cap. Set production packer. Test the tubing and tubing- annulus separately to 3500 psi. · Install the wellhead and test to 5000 psi. Release the drilling rig. · The drilling fluid program and surface system will conform to the regulations set forth in the AOGCCRegulations - 20 AAC 25.033. AJternate Well (DW~2) Construction If an alternate disposal well should be required, DW-2 will be drilled to a location now planned approximately 2000 feet east of DW-l. It will be cased and completed like DW-l. This is illustrated in Exhibit 12. If well DW-2 is drilled, it is currently planned as a sidetrack of DW-1 so that the surface location would be the same. The well would kick out near the shoe of the surface casing, be drilled to 5356 feet TVD, and have a projected bottom hole location of: Latitude. . . Longitude. . . 70 deg, 29 min, 44 sec North 150 deg, 13 min, 52sec West If mechanically, or for some other reason, it is not prudent to drill DW-2 as a sidetrack of DW-1 the surface location will change a slight amount and it could become a grass-roots well. Pioneer Natural Resources Page 11 March 2007 Oooguruk Developmentlect APPI.n for Disposal Injection Order Waste Types and Volumes 20 AAC 252 (c) 7 Sources and Volumes of Wastes Drilling and production wastes to be injected are RCRA exempt as listed in the EP A guidance booklet, EPA 530-K-95-003 and other publications. It is anticipated that wastes injected into the Class II well will be generated at the drillsite. Some other associated exempt fluids will also be injected with a small amount likely to come from onshore sources since there will be an ice road part of most years. These off site sources will be manifested and certified as exempt before being accepted for disposal. The following table provides an estimate of where wastes will come from and the volume of each major category. At the end of development drilling in about 3 years, about 500,000 Bbls will have been injected with almost all coming from drilling operations. The following 20 years of production operations will generate little waste with most coming from infrequent well workover operations. This projection shows a total of 780,000 Bbls could be disposed of over the life of the project. Disposal Volumes by Major Category (20+ years) Drill Cuttings, mud, flush water 500,000 Bbls (3 years) Well workover fluids and flush Other exempt fluids Further drilling operations 120,000 Bbls 80,000 Bbls 80,000 Bbls 780,000 Bbls (20 years) Total (20+ years) 780,000 Bbls Compatibility of Fluids and Formation The regulations require defining physical, chemical, and radiological characteristics of the receiving formation. Toward this end, near-by log data and existing rock and fluid samples are the basis for the descriptions included in Section (c) 4. Open hole and cased hole logs will be run on the disposal welles) as detailed in Section (c) 6. In addition, these same wastes have been injected into similar formations at this depth in numerous places on the North Slope, at much higher volumes and rates for over 25 years without a problem. Therefore, no core samples or formation fluid sampling is planned since this data and extensive operational experience is readily available. Pioneer Natural Resources Page 12 March 2007 · Oooguruk Development Project APPlica.or Disposal Injection Order Injection Pressures 20 AAC 25.252 (c) 8 Iniection Rate and Pressure Injection will occur on an intermittent basis in batches of about 1000 barrels and at an expected rate of 2.5 BPM. This will consist mainly of drilling muds, slurried drill cuttings, well completion fluids, desalination equipment effluent, and camp wastewaters. On rare occasions a larger batch might get injected and the rate could be greater that 2.5 BPM, however, this will be limited by pump capacity and wellhead pressure. At an injection rate of approximately 2.5 BPM injection pressures are expected to be as follows: 1. Average Injection Pressure 2. Maximum Injection Pressure 1800- 2300 psi 3500 psi It is anticipated that on occasions the maximum pressure will be reached due to minor plugging from entrained solids accumulating in and around the wellbore; where-upon the well would need to be surged with clear fluid, and in an extreme case a well stimulation would be initiated. Pioneer, therefore, recommends that an injection pressure limit of 3500 psi be recognized, and that temporary surges and stimulation treatments could exceed the 3500 psi. (The wellhead is rated at 5000 psi). Well Stimulation The objective of any injection well stimulation program is to achieve and maintain the required injection rate at minimum pressure. The Torok Formation is moderately tight. Under normal conditions it would not need typical chemical stimulation treatments often conducted in very tight formations. However, plugging and flow could occur due to mud and solids injection and injectivity could become restricted. If surging with clear fluid does not rectify the problem sufficiently, it is conceivable that a xylene, acid, solvent/surfactant, or other type treatment would be employed to restore injectivity. In such an instance the chemicals would be displaced into the formation and not back- flowed to the surface. Alternately a fill clean out or perforation might be employed. Pioneer Natural Resources Page 13 March 2007 · Oooguruk Development Project APPIiC! for Disposal Injection Order Waste Confinement 20 AAC 252 (c) 9 Reservoir Fracturine A modeling study was undertaken to help quantify the behavior of injecting solids-slurry into the Torok Formation. An industry-available three dimensional hydraulic fracturing simulator was used to predict fracture growth during slurry injection. A prominent licensed commercial product was employed; built and maintained by Meyer and Associates, Inc. for industry use. The study was conducted by an ASRC Energy Services geophysical expert. Rock properties used in the model were based on laboratory core experiments from near- by wells and data from nearby sonic log derived parameters. Disposal well DW-l is planned to be completed in the lower section of the Torok as an open hole completion with the casing shoe set in the mid-Torok shale member. Several completion options are possible; however, the lower section is planned to be used first. This is illustrated in Exhibit 13. If there is a need, perforations can be added either in the shale member or directly in the upper Torok section. Disposal of drilling slurry and other wastewaters will be made in batches of about 1000 Bbls. The slurry is typically about 9.5 pounds per gallon (ppg) and is injected at about 2.5 BPM. Cases were also run using 10.1 ppg slurry, a rate of 4 BPM, and for volumes at 2500 Bbls. The different fracture geometries that developed for the various types of completion scenarios was also investigated for the above operating conditions. Thirty-two cases were run. Exhibit 14 summarizes results from these many cases. Exhibit 15 shows 10 typical fracture profiles from the 32 cases. It can be seen that fracture half-lengths ranged from about 400 feet out to about 800 feet. A sensitivity case using the most extreme operating conditions generated a fracture of 980 feet and is shown as the last profile in Exhibit 15. (The full 42 page ASRC fracturing report is available upon request.) In no cases were the arresting zones penetrated, even when only the upper portion of the Torok was used. Wastes were confined to the injection zone under all excessive conditions. With the batch type operation that will be occurring in the field, there will be ample time for any fracture to heal between injection cycles, and, ultimately for a radial type disposal domain to develop as the project proceeds. Reservoir Faultine There are no Transmissive faults in the general area. The few minor faults that exist are distant and have little throw and the Torok is juxtaposed against the Hue shale, which provides a positive seal at this boundary. This was substantiated in a pair of offset wells Pioneer Natural Resources Page 14 March 2007 . Oooguruk Development Project APPliln for Disposal Injection Order where oil was on the up-thrown side of a minor fault and the well on the down-thrown side was wet, as discussed in Section (c) 4. Waste Placement Exhibit 16 shows where the waste plume will be located after 20+ years of disposal with a 980 foot radial fracture system. With no horizontal pressure gradient in the Torok the plume will not migrate. Un cemented WeUbores Thec10sest existing well to the disposal locations is more than Y2 mile away. It is anticipated that a few of the secondary Kuparuk oil formation wells will penetrate the Torok within Y2 mile of the DW-1 disposal well. These wells will be drilled early in the program. They will be cased and the annuli sealed thru the disposal interval with cement and weighted jelled mud. There should be no leakage from the injection zone of injectant or insitu Torok saline water. Conclusions · Confinement problems will not occur due to hydraulic fracturing during waste disposal operations. · There are no fault transmissibility issues. · There should not be any uncemented wellbore problems. · The waste plume will be quite small and will not migrate when injection ceases. Pioneer Natural Resources Page 15 March 2007 · Oooguruk Development Project APPlica!or Disposal Injection Order Formation Water Salinity 20 AAC 252 (c) 10 & 11 Formation Water Calculations In the absence of abundant formation water samples, water salinities were calculated in ten wells using available log data and the RW A method. The location of the wells used for the salinity calculations spread approximately six miles around the proposed disposal location. The ten well locations are shown on the Exhibit 17. Porosities for the calculations were derived from the density log using a sand matrix with a grain density of 2.65 g/cc. Resistivity values are from the deepest resistivity log available in each well. An apparent water resistivity (RW A) was calculated using the following equation, where RT=deep resistivity, PHI=density porosity, m=2.15, and a=0.62 (Humble coefficients). Rwa = (RT * PHI^m) / a The R W A was temperature-corrected using the following equation, where Tf is the formation temperature at the measurement point. The formation temperatures were derived from gradients interpolated in each well from wireline log BHT measurements at casing points and TD. Rwa @ 75 degF = Rwa * (Tf+ 6.77) / (75 + 6.77) Total Dissolved Solids (TDS) values in parts-per-million were calculated usmg the equation taken from standard Baker Atlas interpretation charts: TDS = 10 ^ «3.562 - log10(Rwa75 - 0.0123» / 0.955) These calculations, along with formation top depths and depths of log measurement points, are tabulated in the charts of Exhibits 8A and 8B. Because the Torok sands are thinly inter-bedded with shales, using averaged values throughout the disposal interval for porosity and resistivity does not yield a calculated TDS representative of the interstitial water. Salinity calculations were therefore performed at specific clean sand depths in each well because they better represent the characteristics of the Torok water. Calculated salinities within the Torok disposal interval range from approximately 17,000- 24,000 ppm NaCl equivalent. There are no other clean sand intervals between the Torok and the upper confining zone to perform calculations on. Pioneer Natural Resources Page 16 March 2007 Oooguruk Development tect APPliln for Disposal Injection Order Formation Water Samples Water samples were obtained during the Arco Kalubik #1 well test of the Albian-Torok interval on April 22, 1992. After flowing 151 barrels to the surface, the average of formation water samples taken at the wellhead yielded a salinity of 24,300 mg/l TDS. The laboratory results compare well with the log calculations. EP A RuliD{~: The EP A ruled their letter of August 18, 2006 that there was no USDW below the top of the confining zone at approximately 4000 feet. The EP A letter is included as Exhibit 19. Accordingly: No aquifer exemption is required. Pioneer Natural Resources Page 17 March 2007 Oooguruk Development Ict APPli.n for Disposal Injection Order Wells Within the AOR 20 AAC 252 (c) 12 There are no existing wells within the area of review. Pioneer Natural Resources March 2007 Page 18 · Oooguruk Development Project APPlicalfor Disposal Injection Order Mechanical Inte2:ritv of In iection Wells 20 AAC 252 (d) & (e) Initial formation testing will involve a pump-in formation breakdown test, followed by a channel log when the well is completed. A static shut-in will be used to obtain a base line reservoir pressure. Subsequent reservoir pressures will be obtained as needed to maintain an understanding of injection zone behavior as detailed below. Visual and automatic monitoring of the inner annulus and tubing pressure will occur routinely with pre-set, out-of-limit, alarms to inform supervisory personnel. The alarm and recording system will remain functional onsite and remotely when the island is unmanned. It is requested that the disposal order allow for changes to the following monitoring plans, as benefit the ongoing operation, consistent with adjustments and approval. Formation Testin2 and Monitorin2: Step Rate Testing: A step rate test will be performed when DW-1 is initially completed using available permanent and drilling rig pumping equipment and tankage on the island. This will generate an injection rate in excess of what will be used for waste disposal and hopefully produce a formation break down. (This could however become more of an injectivity test than a break down). Channel Logging: A channel log will be run upon initial completion, most probably during or following the step rate test, and most probably be an oxygen activation log. Subsequently, it is proposed to run a temperature log annually to confirm waste confinement while the well is in continuous operation. This will also be done annually if there is disposal well or other activity on the island, but not if the well is shut-in and the island unmanned as planned. It is requested that the order recognize this situation and allow scheduling this activity around the normally unmanned operation. Accordingly, for operational and cost efficiency, it is requested that a several month grace period be written into the order to accommodate an extension of any annual due-date. Pressure Falloff ¡Shut-in Pressure Surveys: There is not a plan to run a pressure falloff (PFO) upon initial completion due to such a small amount of unstable injection at this point. A static survey will be as useful in obtaining a base line reservoir pressure. A PFO can be run in subsequent years if the well is active and in a stabilized condition. If the well is shut in for long periods during the Pioneer Natural Resources Page 19 March 2007 Oooguruk Development .ct APPliCI for Disposal Injection Order production phase when the island is unmanned, long term shut-ins can be used to monitor reservoir pressure. It is requested that the order recognize this situation and allow for implementing this as envisioned. Annulus Pressure Testine:: The inner annulus will be tested to 3500 psi upon initial completion and subsequently yearly when the well is active or people are on the island. It is requested that the order recognize this situation and allow scheduling this activity around the normally unmanned operation. Accordingly, it is requested that a several month grace period be written into the order to accommodate an extension of the annual due-date to accommodate operational and cost efficiency. Pioneer Natural Resources Page 20 March 2007 FloWline Flowline Native Kuparuk River and Milne Point Oil & Gas Units --- Federal/State WatersE30undary Oooguruk Tie-in o 1 2 Miles NAD27, AK State Plane Zone 4. Umiat Meridian. Bathymetry in feet (MLLW). MLLW;Mean LQwer LowWater Salt and Brackish Water Marshes provided by NQAA 2 .. " -4250 -6000 -6250 .. -6500 Disposal Well Proposed Completion X Nipple 3813" 10 4-112" 126# L-8C IBT-M 3 95E" 10 X Nipple 3 813" 10 7" )( 4-Y,,' Packer ~5 000 MDrkb X Nipple 3 813" 10 XN Nipple 3 725" 10 WLEG assy 5076 MDrkt 1 5020 TVDss 7" 26# L-BC BTC-M 6 Comments Proposed Completion Exhibit 10 DW-1 Well Schematic 8 1 o (6.381 c SECTION ).) SCALE 9/64 8 ~ (21. S6) J A SECTION C.c 8 , MODn IAN(· LNIUJt-l 6 ,; ¢ .J ¿> I"""~ SECTION B-B SCALE 3/32 6 ,; ¿> ¢ .J o 8 Exhibit 11 vetca Vetco Gray lAIOUT 1 swr lHW0439-2 A ... . 11II11 ~ rs , PROI( 8 1 6 o o (11.81 ) ï c 8 ~ 10 (31.691 j (IO.I(!) A A 8 1 Proll MODEL PARAMS REV.VER: Proll DRAWING PARAMS REV.VER: 1.6 1.6 IØU IAN(· LHltU,·2 5 1 (26.35) o 4 .J I ( 101.251 r-r=(16.94J 161.43) .. ~,.. '" ,."",. I (II' 5000 PSII (10.101 o r-C 12.32) i (26.001 TOP Of GRAT I NG SCALE 7/64 8 Exhibit 11 vetco- Vetco Gra lAYOUT ISlE LAYOUT, IIB-233, IIULT I-BOWL HEAD ASSY A W¡VALVES fOR PIONHR ALASKA COMPLETE W¡UPPER VALVE 01 SPOSAL WELL lHI0439-2 .,. . II(l1lCSl .....'M I .l4IllttI.1 =r=- -EJ REt LEVEL: R.I.os.d BRANCH:- moin REl LEVEL: R.I....d BRANCH:- moin .J I PlOI( Contingency X Nipple 3 813" 10 280E MOrkb I 275C NOSE MOrkb I 4040 NOSE Exhibit 13 Completion Options Kal 1 1650000] 0.75 4850 4950 ~ 5050 5150 o 50 Gamma Ray (GAPI) . ---- .~~_.. Exhibit 14 ~___ _ _ _ _ ___ _ __~ orok Fractu~eling 1Qr_Qº~guryk __~~~~º---- 1__ «( Dimensions vary depending upon how well is completed. Numbers shown are averages ))) n_~T~=__-=- -- ! EXpected'Votu~~n, ~~ =- Hn--__±_n~ _~t~ls~ ::?m-= Bml!tês Case""ijt2';b;:il~lii¡r:fI····:>~li!iìil !gj~~~!!Iat~H~¡!~.j i¡>¡¡¡jll~ I ----------- ------- I --- rac Half length Feet, Approximate 440. 550-700 rac Total Height (up-plusdown)-~ Feet, Approximate 120- r 30 rac Width ----------- - - ínche~2_Ap~r9~Tmate 0.1 f 11 : ---..-.-- 700-830 ------- 130 ----...- 0.14 550 125 0.12 Feet, Approximat~___ Feet, Approximate nches, Approximate I -----tRateSensivity --~~ F:rac Half length Frac Toté3I._Heigh_tlup plus down) Frac Width i -~-- 2500 BBls i 35' 10 QJ.-----f-----~~ ¡ - +-- IS af4$PM _r~OOBblst ~380 . 140 0.: ---¡--~~- 1 . - 480 160 0.18 1000 Bbls ---~ Feet, Approximé3~ Feet, Approximate I!:,ches, Approximate Heavy Slurry Sensivity Frac Half length _ Frac T~!?U1eight (uPJ)!~s~own) Frac Width -- , -'"'"1 --I 570-980 --~~- 140-230 0.22-0.24 Feet, APProx~:~fe- Feet, Approximate Inches, Approximate Heavy Slurry and Rate Sensivity Frac Half length Frac Total Height (up plu~~own) __ Frac Width . . Exhibit 15 Typical Fracture Profiles . . Simulation of Slurry Injection: Ooorguk Beaufort Sea Offshore Drilling Island Injection into Torok Sand Prepared for: PIONEER NATURAL RESOURCES ALASKA, INC. 700 G Street, Suite 600 Anchorage, Alaska 99501 Prepared by: ASRC Energy Services E&P Technology, Inc. AESET -07-Rl January 2007 Stress o Width (in.) 2ttI DJ Length (ft) &IJ figure C-2. This is the inferred geometry after flush (displacement volume) at: shut-in for Case BPM, 9.5 ppg slurry, 1,000 BBl, injection into all barefoot lower section, lower Torok sand). Stress Width Profiles Width Contours Q > f-< a Width (in.) 11JJ DJ 4n:I figure C-4. This is the inferred geometry after flush (displacement volume) at shyt-in for Case 1d (2.5 BPM, 9.5 ppg slurry, 1,000 BBl, injection into shale/silt above the shoe). Stress o Width (in.) 1tJJ 2IIJ Length (ft) :m om figure C-3. This is the inferred geometry after flush (displacement volume) at shut..in for Case lc (2.5 BPM, 9.5 ppg slurry, 1,000 BBl, injection into upper Torok sand. Stress Q ~, ¡: JS[JJ Stress (psi) o Width (in.) &IJ 6!)J figure C-1. This is the inferred geometry after flush (displacement volume) at shut...in for Case 19 {2.5 BPM, 9.5 ppg slurry, 2,500 BBl, injection into upper Torok sand. Stress <2 OS2 > !-< :mJ ~ <1m -!J.t Stress (psi) o Width (in.) U1J &1J 61]] figure C-l0. This is the inferred geometry after flush (displacement volume) at~hut- in for Case 2b (4 BPM, 9.5 ppg slurry, 1,000 BBl, injection into all barefoot lower section, lower Torok sand). Stress g C:i > !-< o Width (in) 61]] mJ figure C-15. This is the inferred geometry after flush (displacement volume) at shut- in for Case 2g (4 BPM, 9.5 ppg slurry, 2,500 BBl, injection into upper Torok sand. 5140 Stress Width Width 5160 a Width (in.) 100 om IŒI <2 '->" C:i >- E-< õ2 sm 3m = Stress (psi) figure C-18. This is the inferred geometry after flush (displacement volume) in for Case 3b(2.5BPM, 10.1 ppg slurry, 1,000 BBl, injection into all barefoot lower section, lower Torok sand). C:i >- E-< Width Contours a Width (in.) m:¡ Length (ft) Figure C-23. This is the inferred geometry after flush (displacement volume) at shut- in for Case (2 BPM, 10.1 ppg slurry, 2,500 BBl, injection into upper Torok sand. em¡ o Width (m.) &IJ <980 §: Q :> b 61 S1:<U 5140 ;m:¡ :ntJ Stress (psi) figure C-31. This the inferred geometry after flush (displacement in for Case 4g (4 BPM, 10.1 ppg slurry, 2,500 BBl, injection into upper sand. 49ro Stress Width Width em¡ &1«1 51&1 52]J :ntJ <ŒJJ -!J2 Stress (psi) m:¡ 1IDJ figure C-32. This is the inferred geometry after flush (displacement volume) at shut- in for Case4h (4 BPM, 10.1 ppg slurry, 2,500 BBl, injection into shale/silt above the shoe). Water Salinities - Torok Formation - Oooguruk Unit Area Base Permafrost Torok Top Torok Base OPERATOR WELL API MD TVDSS MD TVDSS MD TVDSS TEXACO COLVILLE DELTA #1 5010320038 1,557' -1,521' 4,617' -4,581' 4,853' -4,817' .. TEXACO COLVILLE DELTA#1A 5010320038 1,557' -1,521' 4,619' -4,583' 4,859' -4,822' TEXACO COLVILLE DELTA #2 5010320047 1 ,480' -1,447' 5,023' -4,990' 5,250' -5,217' UNOCAL E. HARRISON BAY #1 5025020001 1,567' -1,534' 5,538' -5,505' 5,633' -5,600' PIONEER IVIK#1 5070320436 1,880' -1,828' 5,198' -5,146' 5,455' -5,403' ARCO KALUBIK #3 5010320251 1450' est. -1400' est. 4,872' -4,788' 5,198' -5,115' ARCO KALUBIK #1 5010320165 1,648' -1,611' 5,000' -4,963' 5,270' -5,233' PIONEER NATCHIQ#1 5070320438 1,697' -1,644' 5,703' -5,236' 5,911' -5,390' PIONEER OOOGURUK #1 5070320437 1,494' -1,443' 5,374' -5,322' 5,565' -5,513' EXXON THETIS ISLAND #1 5010320190 1,592' -1,558' 5,531' -5,497' 5,670' -5,636' . TEXACO COLVILLE DELTA #3 5010320048 1,664' -1,631' 4,963' -4,930' 5,200' -5,167' ARCO KALUBIK #2 5010320252 1600' est. -1566' est. 4,889' -4,855' 5,125' -5,091' AMER HESS COLVILLE DEL T A #25-1 5010320054 1,671' -1,623' 4,136' -4,088' 4,318' -4,270' GULF COLVILLE DELTA ST #1 5010320002 Torok disposal interval not present. ARCO KUUKPIK #3 5010320187 Torok disposal interval not present. ARCO TI LL #1 5010320189 Torok disposal interval not present. Water Salinities - Torok Formation - Oooguruk Unit Area Measurement Pt. Fm. TEMP Porosity Rt Rwa @ 75 degF NaCI Equiv OPERATOR WELL MD TVDSS (deg F) (%) (ohm-m) (Humble) (Humble) TEXACO COLVILLE DELTA #1 4,637' -4,601' 116.7 20 3.4 0.26 23,690 4,701' -4,665' 117.7 21 3.5 0.30 19,660 . COLVILLE DELTA#1A 4,798' -4,762' 118.2 21 3.8 0.33 17,770 4,852' -4,815' 119.1 21 3.5 0.32 18,630 COLVILLE DEL T A #2 5,133' -5,100' 131.7 17 5.6 0.34 17,140 5,210' -5,177' 133.4 16 6.0 0.31 19,040 E. HARRISON BAY #1 5,588' -5,555' 146.1 15 6.2 0.30 19,870 5,621' -5,588' 146.5 16 5.7 0.34 17,530 IVIK#1 5,248' -5,196' 124.4 16 5.0 0.26 23,130 5,431' -5,379' 129.4 20 3.2 0.27 22,470 KALUBIK #3 5,108' -5,025' 109.8 19 4.1 0.27 21,820 5,116' -5,033' 110.0 18 4.5 0.27 21,970 KALUBIK #1 5,187' -5,150' 129.5 16 4.9 0.26 23,360 . 5,236' -5,199' 130.1 18 4.2 0.27 22,010 NATCHIQ #1 5,740' -5,263' 123.4 16 6.2 0.32 18,620 5,763' -5,279' 123.9 19 3.6 0.26 22,810 OOOGURUK #1 5,423' -5,371' 132.5 16 4.9 0.28 21,680 5,460' -5,408' 133.5 21 3.1 0.32 18,620 THETIS ISLAND #1 5,583' -5,549' 137.1 17 5.1 0.33 18,010 5,603' -5,569' 137.5 15 6.2 0.31 19,190 . . Exhibit 19 ~st...~ tb ^ t, ; ~.z \;~=:;J UNITED STATES ENVIRONMENTAL PROTECTION AGENCY . REGION10 1200 Sixth Avenue Seattle, WA 981 01 1 8 AUG 2006 RECEIVED AUG 2 3 2006 BY: Reply To Attn Of: aCE 127 Mr. John Hellen Pioneer Natural Resources Alaska, Inc (PIONEER) RegulaJory and Envìronmental Coordinator 700 G Street, Suite 600 Anchorage, Alas~a 99501 Re: No Underground Sources of Drinking Water (USDW) Ruling Oooguruk Drill Site (ODS) Class I Well Application, Beaufort Sea, North Slope, Alaska. Dear Mr. Hellen: The U.S. Environmental Protection Agericy (EPA), Region 10, Office of Compliance and Enforcement, has received PIONEER's letters dated June 5, and August 8, 2006, respectively. These letters requested that EPA confil111 that portions of aquifers beneath ODS, Beaufort Sea, North Slope, Alaska, do not qualify as underground sources of drinking water (USDWs) as defined in 40 CFR§l44.3.Based upon a review of the infol111ation provided by PIONEER, EPA confinns the "No USDW" ruling for the portions of aquifers requested by PIONEER. In summary, the ODS aquifers within a 1h mile radius of the two candidate wells within the correlative intervals (referenced in the Arco Kalubik-1 type log) below the Hue Shale marker (at approximately 4000 feet true vertical depth subsea (tvdss» to the base of theHRZ Shale marker (at approximately 5800 feet tvdss) for the. two proposed Class I injection wells (DW-l, . . and DW-2) are nota USDW. Well DW-1 is planned as a straight hole vertically below the island, while Well DW-2 is planned as.a contingency back-up to Well DW-l. These aquifers exhibit total dissolved solids concentrations that significantly exceed the 10,000 milligrams per liter (mg/l) IDS threshold for a USDW. The Class I well will be used to inject slurried drilling mud and cuttings, well test and completion fluids, stimulation fluids, camp wastewater, stOI111 water, other exempt wastes, and perhaps a small amount of non-hazardous, non-exempt wastes. In the event that the operator sidetracks the candidate wells or drills new wells from ODS, the operator has the flexibility to substitute another well that must be pre-approved by the EP A and demonstrate its mechanical integrity prior to initiation of Class I injection activities. . . - 2- For each potential Class I well, the "No USDW" ruJing applies to the area extending Ih mile radius from the center of each candidate well location which includes: Well No./Facility DW-l We]) Oooguruk Drill Site DW-2 WeB Oooguruk Drill Site Surface Location LatitudelLon£itude Lat 70.4958 deg N/ Long 150.2467 deg W Lat 70.4923 deg N/ Long 150.2423 deg W If you have any questions or need clarification, please contact Mr. Thor Cutler of my staff at (206) 553-1673. SinCerelY') ..... ../7.1 .' .,(... C)/ {L 2-./. Michael ~Bu;kl, Director ' Office of Compliance' and Enforcement cc: Thor Cutler, EP A Region 10, Seattle, W A Jim Regg, AOGCC, Anchorage, AK TaJib Syed, EP A Consultant, Denver, CO