The Kerrobert THAITM project is a 50/50 joint venture with Baytex Energy Trust. This joint venture project highlights the global applicability of THAITM technology in conventional heavy oil resources. We believe that a significant portion of the estimated 20 billion of barrels of unrecovered conventional heavy oil resource in
At Kerrobert, we have been on continuous air injection and the wells have been on production since late October. Since this project involves mobile oil, our original plan was to utilize temporary hydraulic pumps on each well to create a drawdown pressure across the horizontal well and, as combustion gas production increased, we would cease pumping and flow the wells by produced gas lift. As previously reported, the initial fluid production volumes were tested at 180 to 300 barrels per day per well, with oil cuts ranging from zero to 40%. However, during the transition phase to gas lift we learned that liquid inflow to the production wells exceeded the pump's capacity, which limited our ability to draw down the wells and also caused frequent pump failures. On December 21, 2009 we re-configured the pump in KP1 to improve its pumping capacity and we are currently re-configuring KP2.
Since the re-configuration, fluid production rates from KP1 have ranged from 250 to 420 barrels per day with oil cuts averaging 36% and reaching as high as 65%. We have also increased the air injection rate to 50,000 m3/day and the produced gas rate has increased to 8,000 m3/day. Well bore temperatures are rising with toe temperatures consistently in the 120 to 140 degrees Celsius range. Produced gas composition confirms high temperature combustion and we have recently measured an improvement in the API and viscosity of the produced oil. We expect to have the KP2 pump reconfigured and producing at similar rates to KP1 within the next few days.
Surface facilities have been operating smoothly with only minor cold weather and early start-up related issues. We have not had any solids or produced sand. The next expansion of our air compression capacity will be installed at the beginning of April. Due to the current pump limitations, we intend to replace them in the near future with a higher capacity design, targeting 500 barrels of oil per day ("bopd") per well. We are also finalizing our plans for the development of the initial earned lands which would encompass up to 20 additional production wells in this portion of the pool. We plan to commence this expansion in the third quarter of this year.
Conklin (Whitesands Project)
At Conklin, we effectively shut-in the majority of our production from August to November to facilitate the re-drilling of the P1 and P2 wells. The P1B and P2B replacement wells were then placed on production at the end of November as planned, and air injection rates have been increased to close to design capacity. In a re-start situation such as this, early production consists of bitumen and condensed steam from the pre-heating period. We are now seeing the expected increase in combustion gas and improving oil quality and oil production rates. P3B has been choked back during the start up of the new wells to manage the gas balance between all three wells.
Total oil production has reached 350 bopd and, although overall facility efficiency has been impacted by severe cold weather, we target increasing total Conklin production to 900 bopd by the end of the first quarter. We have now revised our maximum target production for the Conklin pilot to 1500 bopd and we anticipate reaching this production level in mid 2010.
May River Project
The regulatory application for
Front-end engineering and design for the
Petrobank Energy and Resources Ltd. is a Calgary-based oil and natural gas exploration and production company with operations in western
Forward Looking Statements. Certain information provided in this press release constitutes forward-looking statements. The words "anticipate", "expect", "project", "estimate", "forecast" and similar expressions are intended to identify such forward-looking statements. Specifically, this press release contains forward-looking statements relating to results of operations, future well performance reserves, and the timing of certain projects. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. You can find a discussion of those risks and uncertainties in our Canadian securities filings. Such factors include, but are not limited to: general economic, market and business conditions; fluctuations in oil prices; the results of exploration and development drilling, recompletions and related activities; timing and rig availability, outcome of exploration contract negotiations; fluctuation in foreign currency exchange rates; the uncertainty of reserve estimates; changes in environmental and other regulations; risks associated with oil and gas operations; and other factors, many of which are beyond the control of the Company. There is no representation by Petrobank that actual results achieved during the forecast period will be the same in whole or in part as those forecast. Except as may be required by applicable securities laws, Petrobank assumes no obligation to publicly update or revise any forward-looking statements made herein or otherwise, whether as a result of new information, future events or otherwise.
Resources and Contingent Resources. In this press release, Petrobank has disclosed estimated volumes of "contingent resources" or "resource" estimates. "Resources" are oil and gas volumes that are estimated to have originally existed in the earth's crust as naturally occurring accumulations but are not capable of being classified as "reserves". The following are excerpts from the definition of "contingent resources" as contained in Section 5 of the COGE Handbook, which is referenced by the Canadian Securities Administrators in "National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities". "Contingent resources" are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political, and regulatory matters, or a lack of markets. It is also appropriate to classify as "contingent resources" the estimated discovered recoverable quantities associated with a project in the early evaluation stage. "Contingent resources" are further classified in accordance with the level of certainty associated with the estimates and may be subclassified based on project maturity and/or characterized by their economic status. "Resources" and "contingent resources" do not constitute, and should not be confused with, reserves.